SECURITIES AND EXCHANGE COMMISSION
                   WASHINGTON, D. C. 20549
                        ____________
                          Form 10-K
                        ____________

[X] ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(D) OF THE
    SECURITIES EXCHANGE ACT OF 1934
    FOR THE FISCAL YEAR ENDED DECEMBER 31, 2000
               OR
[ ] TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(D) OF THE
    SECURITIES EXCHANGE ACT OF 1934

               Commission File Number 1-13159

                         ENRON CORP.
   (Exact name of registrant as specified in its charter)

        Oregon                           47-0255140
(State or other jurisdiction          (I.R.S. Employer
of incorporation or organization)    Identification No.)

                       ENRON BUILDING
        1400 Smith Street, Houston, Texas 77002-7369
     (Address of principal executive offices) (zip code)
Registrant's telephone number, including area code:
713-853-6161
                        ____________
 Securities registered pursuant to Section 12(b) of the Act:
Title of each class              Name of each exchange
                                 on which registered

Common Stock, no par value      New York Stock Exchange;
                                Chicago Stock Exchange;
                                and Pacific Stock Exchange

Cumulative Second Preferred     New York Stock Exchange
Convertible Stock,              and Chicago Stock Exchange
     no par value

7% Exchangeable Notes due       New York Stock Exchange
July 31, 2002

Securities registered pursuant to Section 12(g) of the Act:
                            None

  Indicate by check mark whether the Registrant (1) has
filed all reports required to be filed by Section 13 or
15(d) of the Securities Exchange Act of 1934 during the
preceding 12 months (or for such shorter period that the
Registrant was required to file such  reports), and (2) has
been subject to such filing requirements for the past 90
days.
  Yes  [X]    No  [ ]

  Indicate by check mark if disclosure of delinquent filers
pursuant to Item 405 of Regulation S-K is not contained
herein, and will not be contained, to the best of
registrant's knowledge, in definitive proxy or information
statements incorporated by reference in Part III of this
Form 10-K or any amendment to this Form 10-K.

  Aggregate market value of the voting stock held by non-
affiliates of the registrant, based on closing prices in the
daily composite list for transactions on the New York Stock
Exchange on February 15, 2001, was approximately
$60,207,479,342.  As of March 1, 2001, there were
754,296,597 shares of registrant's Common Stock, no par
value, outstanding.

  Documents incorporated by reference.  Certain portions of
the registrant's definitive Proxy Statement for the May 1,
2001 Annual Meeting of Shareholders ("Proxy Statement") are
incorporated herein by reference in Part III of this Form
10-K.

<PAGE>

                      TABLE OF CONTENTS

                           PART I
                                                             Page

Item 1.  Business                                             1
          General                                             1
          Business Segments                                   1
          Transportation and Distribution                     2
          Wholesale Services                                  5
            Developed Markets                                 7
            Developing Markets                                8
          Retail Energy Services                             11
          Broadband Services                                 11
          Other Enron Businesses                             12
          Regulation                                         13
          Current Executive Officers of the Registrant       19

Item 2.  Properties                                          21
          Natural Gas Transmission                           21
          Electric Utility Properties                        21
          Domestic Power Plants                              22
          International Power Plants, Pipelines
             and Electric Utility Properties                 23

Item 3.  Legal Proceedings                                   23

Item 4.  Submission of Matters to a Vote of Security Holders 25

                           PART II

Item 5.  Market for the Registrant's Common Equity
            and Related Shareholder Matters                  26

Item 6.  Selected Financial Data (Unaudited)                 27

Item 7.  Management's Discussion and Analysis of
            Financial Condition and Results of Operations    28

Item 7A. Financial Risk Management                           43

          Information Regarding Forward Looking Statements   46

Item 8.  Financial Statements and Supplementary Data         47

Item 9.  Changes in and Disagreements with Accountants
            on Accounting and Financial Disclosure           47

                          PART III

Item 10. Directors and Executive Officers of the Registrant  48

Item 11. Executive Compensation                              48

Item 12. Security Ownership of Certain Beneficial Owners
            and Management                                   48

Item 13. Certain Relationships and Related Transactions      49

                           PART IV

Item 14. Exhibits, Financial Statement Schedules, and
            Reports on Form 8-K                              49

<PAGE>
                           PART I

Item 1. BUSINESS
                           GENERAL

     Headquartered in Houston, Texas, Enron Corp., an Oregon
corporation, provides products and services related to
natural gas, electricity and communications to wholesale and
retail customers.  Enron's operations are conducted through
its subsidiaries and affiliates, which are principally
engaged in:

  *    the transportation of natural gas through pipelines to
     markets throughout the United States;

  *    the generation, transmission and distribution of
     electricity to markets in the northwestern United States;

  *    the marketing of natural gas, electricity and other
     commodities and related risk management and finance services
     worldwide;

  *    the development, construction and operation of power
     plants, pipelines and other energy related assets worldwide;

  *    the delivery and management of energy commodities and
     capabilities to end-use retail customers in the industrial
     and commercial business sectors; and

  *    the development of an intelligent network platform to
     provide bandwidth management services and the delivery of
     high bandwidth communication applications.

     As of December 31, 2000, Enron employed approximately
20,600 persons.

     As used herein, unless the context indicates otherwise,
"Enron" or the "Company" refers to Enron Corp. and its
subsidiaries and affiliates.

                      BUSINESS SEGMENTS

     Enron has divided its operations into the following
reportable segments:

     Transportation and Distribution - Regulated industries;
interstate transmission of natural gas; management and
operation of pipelines; electric utility operations.

     Wholesale Services - Commodity sales and services, risk
management products and financial services to wholesale
customers; development, acquisition and operation of power
plants, natural gas pipelines and other energy-related
assets.

     Retail Energy Services - Sales of natural gas and
electricity and related products directly to end-use
customers, particularly in the commercial and industrial
sectors, and the outsourcing of energy-related activities.

     Broadband Services - Construction and management of a
nationwide fiber- optic network, the marketing and
management of bandwidth and the delivery of high-bandwidth
content.

     Corporate and Other - Includes operation of water,
renewable energy businesses and clean fuels plants, as well
as overall corporate activities.

     For financial information by business segment for the
fiscal years ended December 31, 1998 through December 31,
2000, please see Note 20 to the Consolidated Financial
Statements, "Geographic and Business Segment Information",
on page F-38.


               TRANSPORTATION AND DISTRIBUTION

     Enron's Transportation and Distribution business is
comprised of the Company's North American interstate natural
gas transportation systems and its electricity transmission
and distribution operations in Oregon.

Interstate Transmission of Natural Gas

     Enron and its subsidiaries operate domestic interstate
natural gas pipelines extending from Texas to the Canadian
border and across the southern United States from Florida to
California.  Included in Enron's domestic interstate natural
gas pipeline operations are Northern Natural Gas Company
("Northern"), Transwestern Pipeline Company ("Transwestern")
and Florida Gas Transmission Company ("Florida Gas") (50%
owned by Enron).  Northern, Transwestern and Florida Gas are
interstate pipelines and are subject to the regulatory
jurisdiction of the Federal Energy Regulatory Commission
(the "FERC").  Each pipeline serves customers in a specific
geographical area:  Northern, the upper Midwest;
Transwestern, principally the California market and pipeline
interconnects on the east end of the Transwestern system;
and Florida Gas, the State of Florida.  In addition, Enron
holds an interest in Northern Border Partners, L.P., which
owns a 70% interest in the Northern Border Pipeline system.
An Enron subsidiary operates the Northern Border Pipeline
system, which transports gas from Western Canada to delivery
points in the midwestern United States.

     Northern Natural Gas Company.  Through its
approximately 16,500-mile natural gas pipeline system
stretching from the Permian Basin in Texas to the Great
Lakes, Northern transports natural gas to points in its
traditional market area of Illinois, Iowa, Kansas, Michigan,
Minnesota, Nebraska, South Dakota and Wisconsin.  Gas is
transported to town border stations for consumption and
resale by non-affiliated gas utilities and municipalities
and to other pipeline companies and gas marketers.  Northern
also transports gas at various points outside its
traditional market area in the production areas of Colorado,
Kansas, New Mexico, Oklahoma, Texas and North Dakota for
utilities, end-users and other pipeline and marketing
companies.  Northern provides transportation and storage
services to approximately 90 utility customers and end-users
in the upper midwestern United States.  Most of Northern's
revenues are comprised of monthly demand charges that are
based on contracted capacity rather than throughput.

     In Northern's market area, natural gas is an energy
source available for traditional residential, commercial and
industrial uses.  Northern's throughput totaled
approximately 1,291 trillion British thermal units ("TBtu")
in 2000.  Northern also operates three natural gas storage
facilities and two liquefied natural gas storage peaking
units.  These storage facilities provide Northern the
operational capacity to balance its system on a daily basis
and assist in meeting customers' heating season system
requirements.  Northern competes with other interstate
pipelines in the transportation and storage of natural gas.

     Transwestern Pipeline Company.  Transwestern is an
interstate pipeline engaged in the transportation of natural
gas.  Through its approximately 2,500-mile pipeline system,
Transwestern transports natural gas from West Texas,
Oklahoma, eastern New Mexico and the San Juan Basin in
northwestern New Mexico and southern Colorado primarily to
the California market and to markets off the east end of its
system.  Transwestern has access to three significant gas
basins for its gas supply: the San Juan Basin, the Permian
Basin in West Texas and eastern New Mexico and the Anadarko
Basin in the Texas and Oklahoma Panhandles.  Additionally,
gas from the Rocky Mountain Basin can access Transwestern
through pipeline interconnections.  Transwestern's peak
delivery capacity was approximately 1.7 billion cubic feet
("Bcf") per day in 2000.  Transwestern and its customers
agreed to contract rates through 2006 and agreed that
Transwestern would not be required to file a new rate case
for rates to be effective prior to November 1, 2006.
Transwestern's current firm capacity for both west and east
flow is fully subscribed under a combination of short-term
and long-term contracts.  Relatively small increments of
operational capacity become available from time to time and
are generally sold on a daily or short-term basis.

     Transwestern's mainline includes a lateral pipeline to
the San Juan Basin which allows Transwestern to access San
Juan Basin gas supplies.  Via Transwestern's San Juan
lateral pipeline, the San Juan Basin gas may be delivered to
California markets as well as markets off the east end of
Transwestern's system.  This bi-directional flow capability
enhances pipeline utilization.  Transwestern added bi-
directional flow capability in 1995 to increase system
flexibility and utilization.  Transwestern has firm
transportation service on the east end of its system and
transports Permian, Anadarko and San Juan Basin supplies
into Texas, Oklahoma and the midwestern United States.  More
recently, Transwestern has modified its operations to
enhance its ability to supply the California market.   In
May 2000, Trans-western completed an expansion which
increased delivery capability to California by 140 million
cubic feet ("MMcf") per day.  Transwestern is pursuing
additional expansions to its pipeline of approximately 50
MMcf per day and 150 MMcf per day with expected completions
in 2001 and 2002, respectively.  Transwestern competes with
several interstate pipelines in the California market and
its markets off the east end of its system.

     Florida Gas Transmission Company.  Enron owns a 50%
interest in Florida Gas by virtue of its 50% interest in
Citrus Corp., which owns all of the capital stock of Florida
Gas.

     Florida Gas is an interstate pipeline company that
transports natural gas for third parties.  Its approximately
4,795-mile pipeline system extends from South Texas to a
point near Miami, Florida.  Florida Gas provides a high
degree of gas supply flexibility for its customers because
of its proximity to the Gulf of Mexico producing region and
its interconnections with other interstate pipeline systems
which provide access to virtually every major natural gas
producing region in the United States.  Florida Gas serves a
mix of customers anchored by electric utility generators.

     Florida Gas has periodically expanded its system
capacity to keep pace with the growing demand for natural
gas in Florida.  In February 2000, Florida Gas received FERC
certification for its Phase IV expansion.  Phase IV will
increase system capacity approximately 200 MMcf per day and
is backed by 20-year firm transportation agreements.  The
Ft. Myers extension, part of the Phase IV expansion which
brought natural gas service to southwest Florida for the
first time, went into service on October 1, 2000.  The
remainder of the Phase IV expansion is scheduled to go in
service in May 2001.  The Phase IV expansion is expected to
cost approximately $250 million.  Florida Gas has also
received preliminary approvals from the FERC for its Phase V
expansion, which will increase capacity an additional
approximately 400 MMcf per day at an estimated cost of $420
million.  Subject to final regulatory approvals, Phase V is
expected to be in service in 2002.  Florida Gas' current
firm average delivery capacity into Florida is approximately
1,495 billion British thermal units ("BBtu") per day.
Florida Gas also owns an interest in facilities that link
its system to the Mobile Bay producing area.  Florida Gas'
customers have reserved over 99% of the existing capacity on
the Florida Gas system pursuant to firm, long-term
transportation service agreements.

     Florida Gas is the only interstate natural gas pipeline
serving peninsular Florida.  Florida Gas faces competition
from residual fuel oil in the Florida market.  In addition,
there is a proposed pipeline project that would compete with
Florida Gas that has received approval from the FERC; the
project sponsor has announced that construction will begin
in June 2001.

     Northern Border Partners, L.P..  Northern Border
Partners, L.P., a Delaware limited partnership, owns 70% of
Northern Border Pipeline Company, a Texas general
partnership ("Northern Border").  An Enron subsidiary holds
an 11.8% interest in Northern Border Partners L.P. and
serves as operator of the pipeline.  Northern Border owns an
approximately 1,214-mile interstate pipeline system that
transports natural gas from the Montana-Saskatchewan border
near Port of Morgan, Montana to interconnecting pipelines
and local distribution systems in the States of North
Dakota, South Dakota, Minnesota, Iowa and Illinois.
Northern Border has pipeline access to natural gas reserves
in the provinces of Alberta, British Columbia and
Saskatchewan, as well as the Williston Basin in the United
States.  The pipeline system also has access to production
of synthetic gas from the Dakota Gasification Plant in North
Dakota.  Interconnecting pipeline facilities provide
Northern Border shippers access to markets in the Midwest,
as well as other markets throughout the United States by
transportation, displacement and exchange agreements.
Therefore, Northern Border is strategically situated to
transport significant quantities of natural gas to major gas
consuming markets. Based upon existing contracts and
capacity, 100% of Northern Border's firm capacity
(approximately 2.4 Bcf of natural gas per day) is fully
contracted under long-term agreements with an average term
of six years.  In March 2000, Northern Border received FERC
approval for Project 2000, an approximately $94 million
proposed expansion and extension of the pipeline system into
the heavy industrial area of northern Indiana.  Construction
has commenced, and the project is expected to be in service
in late 2001.  Northern Border competes with two other
interstate pipeline systems that transport gas from Canada
to the Midwest.

Crude Oil Transportation Services

     EOTT Energy Partners, L.P. ("EOTT"), a Delaware limited
partnership, is engaged in the purchasing, gathering,
transporting, trading, storage and resale of crude oil and
refined petroleum products, and related activities.  EOTT
Energy Corp. (a wholly-owned subsidiary of Enron) serves as
the general partner of EOTT.  Enron owns a minority interest
in EOTT.  Through its North American crude oil gathering and
marketing operations, EOTT purchases crude oil produced from
approximately 40,000 leases in 18 states and is a purchaser
of lease crude oil in Canada.  EOTT provides transportation
and trading services for third party purchasers of crude
oil.  EOTT competes with the crude oil marketing affiliates
of major oil companies and with smaller independent
marketers.

Electricity Transmission and Distribution Operations

     Enron's electric utility operations are conducted
through its wholly-owned subsidiary Portland General
Electric Company ("PGE").  PGE is engaged in the generation,
purchase, transmission, distribution and sale of electricity
in the State of Oregon.  PGE also sells energy to wholesale
customers throughout the western United States.  PGE's
Oregon service area is approximately 3,150 square miles,
including 51 incorporated cities of which Portland and Salem
are the largest, within a state-approved service area
allocation of 4,070 square miles.  As of December 31, 2000
PGE served approximately 725,000 customers.

     Enron and Sierra Pacific Resources announced on
November 8, 1999 that they had entered into a purchase and
sale agreement whereby Enron will sell PGE to Sierra Pacific
Resources for $2.1 billion, comprised of $2.02 billion in
cash and the assumption of Enron's approximately $80 million
merger payment obligation.  Sierra Pacific Resources will
also assume $1 billion in PGE debt and preferred stock.  The
proposed transaction, which is subject to regulatory
approvals and closing conditions, has been delayed by the
effect of recent events in California and Nevada on the
purchaser.

     PGE serves a diverse retail customer base.  Residential
customers constitute the largest customer class and
accounted for approximately 43% of the retail revenues in
2000.  Residential demand is highly sensitive to the effects
of weather, with revenues highest during the winter heating
season.  Commercial customers comprised approximately 37%
and industrial customers represented approximately 20% of
retail revenues in 2000.  The commercial and industrial
classes are not dominated by any single industry.  While the
20 largest customers constituted approximately 21% of 2000
retail demand, they represented eight different industrial
groups including paper manufacturing, high technology, metal
fabrication, general merchandising and health services.  No
single customer represents more than 3.5% of PGE's total
retail load.

     PGE operates within a state-approved service area and
under current regulation is substantially free from direct
retail competition with other electric utilities.  PGE's
competitors within its Oregon service territory include
other fuel suppliers, such as the local natural gas company,
which compete with PGE for the residential and commercial
space and water heating market.

                       WHOLESALE SERVICES

     Enron's wholesale business ("Wholesale Services")
includes its worldwide wholesale energy and other
commodities businesses.  Wholesale Services operates in
developed markets such as North America and Europe, as well
as newly deregulating or developing markets including Japan,
Australia, South America and India.

     Enron builds its wholesale businesses through the
creation of networks involving selective asset ownership,
contractual access to third-party assets and market-making
activities.  Each market in which Wholesale Services
operates utilizes these components in a slightly different
manner and is at a different stage of development.  This
network strategy has enabled Wholesale Services to establish
a significant position in its markets.  Wholesale Services'
activities are categorized into two business lines:  (a)
Commodity Sales and Services, and (b) Assets and
Investments.  Activities may be integrated into a bundled
product offering for Enron's customers.

     Wholesale Services manages its portfolio of contracts
and assets in order to maximize value, minimize the
associated risks and provide overall liquidity.  In doing
so, Wholesale Services uses portfolio and risk management
disciplines, including offsetting or hedging transactions,
to manage exposures to market price movements (commodities,
interest rates, foreign currencies and equities).
Additionally, Wholesale Services manages its liquidity and
exposure to third-party credit risk through monetization of
its contract portfolio or third-party insurance contracts.
Wholesale Services also sells interests in certain
investments and other assets to improve liquidity and
overall return, the timing of which is dependent on market
conditions and management's expectations of the investment's
value.

     Commodity Sales and Services.  Wholesale Services
provides reliable commodity delivery and predictable pricing
to its customers through forwards and other contracts.  This
market-making activity includes the purchase, sale,
marketing and delivery of natural gas, electricity, liquids
and other commodities, as well as management of Wholesale
Services' own portfolio of contracts.  Wholesale Services'
market-making activity is facilitated through a network of
capabilities including selective asset ownership.  In late
1999, Wholesale Services launched an Internet-based e-
commerce system, EnronOnline, which allows wholesale
customers to view Enron's real time pricing and complete
commodity transactions with Enron as principal, with no
direct interaction.

     Wholesale Services markets, transports and provides
energy commodities as reflected in the following table
(including intercompany amounts):

<TABLE>
<CAPTION>
                                      Year Ended December 31,
                                      2000      1999      1998

<S>                                <C>       <C>       <C>
Physical Volumes (BBtue/d)(a)(b)
Gas:
  United States                     17,674     8,982     7,418
  Canada                             6,359     4,398     3,486
  Europe and Other                   3,637     1,572     1,251
                                    27,670    14,952    12,155
Transportation volumes                 649       575       559
   Total gas volumes                28,319    15,527    12,714
Crude oil and Liquids                6,088     6,160     3,570
Electricity(c)                      17,308    10,742    11,024
   Total physical volumes (BBtue/d) 51,715    32,429    27,308
Electricity volumes (thousand MWh)
  United States                    578,787   380,518   401,843
  Europe and Other                  54,670    11,576       529
     Total                         633,457   392,094   402,372

Financial settlements (notional)
(BBtue/d)                          196,148    99,337    75,266

<FN>
 (a) Billion British thermal units equivalent per day.
 (b) Includes  third-party transactions  by  Enron  Energy
     Services.
 (c) Represents electricity volumes marketed, converted to
     BBtue/d.
</TABLE>

     During 2000, Wholesale Services strengthened its
position in the deregulated North American gas markets and
deregulating power markets.  Enron also continued to expand
its presence in Europe, particularly on the Continent where
wholesale markets began deregulation in early 1999.  New
product offerings in coal, metals, steel and pulp and paper
markets also added favorably to the results.

     Assets and Investments.  Wholesale Services' businesses
make investments in various energy and certain related
assets as a part of its network strategy.  Wholesale
Services either purchases the asset from a third party or
develops and constructs the asset.  In most cases, Wholesale
Services operates and manages such assets.  Additionally,
Wholesale Services invests in debt and equity securities of
energy and technology-related businesses, which may also
utilize Wholesale Services' products and services.  With
these merchant investments, Enron's influence is much more
limited relative to assets Enron develops or constructs.
Wholesale Services uses risk management disciplines,
including hedging transactions, to manage the impact of
market price movements on its merchant investments.

Developed Markets

     North America

     Enron purchases, markets and delivers natural gas,
electricity and other commodities in North America.
Customers include independent oil and gas producers, energy-
intensive industrials, public and investor-owned utility
power companies, small independent power producers and local
distribution companies.  Enron also offers a broad range of
price, risk management and financing services including
forward contracts, swap agreements and other contractual
commitments.   Enron's strategy is to enhance the scale,
scope, flexibility and speed of its North American energy
businesses through developing and acquiring selective
assets, securing contractual access to third party assets,
forming alliances with customers and utilizing technology
such as EnronOnline.  With increased liquidity in the
marketplace and the success of EnronOnline, Enron believes
that it no longer needs to own the same level of physical
assets, instead utilizing contracting and market-making
activities.

     Europe

     As the energy markets liberalize across Europe, Enron's
strategy is to build a presence early in each key market in
order to create a pan European energy business that provides
similar energy service capabilities and products to those
established in North America.  Services include delivery of
physical commodities, price risk management and financing
services. At the end of 2000, Enron employed approximately
2,400 people across Europe including the United Kingdom,
Norway, Germany, Turkey, Poland and Italy.

     Enron's activity in the United Kingdom, which
liberalized its energy markets in 1992, includes well-
established natural gas and power marketing operations.  The
development, construction and operation of energy assets and
the acquisition of selected assets have contributed to the
expansion of Enron's energy marketing business in the United
Kingdom.

     Enron has an office in Oslo which accesses the power
marketing opportunities available in the Nordic region, the
most open market for power trading in the Europe region.
Enron provides power risk management services to regional
municipalities, utilities and large industrials.  Enron is
also pursuing opportunities in continental Europe where
there is a need for customized, flexible energy supply
contracts to benefit from liberalizing gas and power
markets.  Enron's power and gas volumes and transactions in
continental Europe are continuing to increase.

     Enron has developed or is developing, owns interests in
and/or operates several power plants across Europe,
including a natural gas fired 116-megawatt power plant in
Poland; a 551-megawatt combined-cycle oil gasification power
plant in Sardinia, Italy; and a 478-megawatt gas-fired power
plant in Turkey.

     Australia and Japan

     Enron has an office in Australia which offers similar
commodity risk management and finance services to those
provided to the North American and European power markets.
The Sydney office provides a strategic platform for the
extension of Enron's coal, metals and broadband businesses,
as well as providing support for Enron's operations in the
Asia-Pacific region.  Enron opened an office in Japan in
October 2000 and is pursuing a similar strategy there.

Developing Markets

     In many markets outside of North America and Europe, a
shortage of energy infrastructure exists, which has provided
Enron with opportunities to develop, construct, promote and
operate natural gas pipelines, power plants and other energy
infrastructure.  In these markets, Enron's strategy is to
facilitate completion of vital energy networks to connect
areas of energy supply to areas where energy is consumed.
By creating energy networks, Enron provides reliable
delivery of physical energy commodities and develops risk
management and financing services to wholesale customers in
key international regions.

     Enron's energy infrastructure projects are, to varying
degrees, subject to all the risks associated with project
development, construction and financing in foreign
countries, including without limitation, the receipt of
permits and consents, the availability of project financing
on acceptable terms, expropriation of assets, renegotiation
of contracts with foreign governments and political
instability, as well as changes in laws and policies
governing operations of foreign-based businesses generally.

     Enron owns or operates various energy assets and
investments in certain developing markets outside of North
America and Europe, including the following:

  *    A 50% voting interest in Dabhol Power Company, which
     developed and owns an electricity generating power plant
     south of Mumbai, State of Maharashtra, India.  Phase I of
     the power plant has an initial capacity of 826-megawatts and
     began commercial operations in May 1999.  Construction on
     Phase II, a 1,624-megawatt combined-cycle power plant to be
     fueled by natural gas, is expected to be completed in late
     2001.  Phase II also includes a liquefied natural gas (LNG)
     terminal which is expected to be completed in mid-2002.  The
     power plant has a 20-year power purchase agreement with the
     Maharashtra State Electricity Board.

  *    A 35% interest in Transportadora de Gas del Sur ("TGS")
     in Argentina.  The 4,104-mile pipeline system has a capacity
     of approximately 1.9 Bcf per day and primarily serves four
     distribution companies in the greater Buenos Aires area
     under long-term, firm transportation contracts.

  *    A 25% interest in Transredes Transporte de
     Hidrocarburos S.A. ("Transredes"), an approximately 3,570-
     mile system of natural gas, crude oil and products pipelines
     located in Bolivia and connecting Bolivian oil and gas
     reserves to major markets in Bolivia.  Enron also developed,
     along with Petrobras, the national oil and gas company of
     Brazil, and others, a pipeline which will connect with
     Transredes in Bolivia and transport natural gas to markets
     in Brazil.  The pipeline project includes an approximately
     1,969-mile natural gas pipeline from Santa Cruz, Bolivia to
     Porto Alegre, Brazil.

  *    An interest in a 480-megawatt combined-cycle power
     plant at Cuiaba in the State of Mato Grosso in western
     Brazil which feeds power into the Brazilian energy grid in
     Cuiaba, at a strategic delivery point having few existing
     alternate generation sources.  Commercial operations of
     Phase I of the project (150 megawatts) commenced in early
     1999.  Commercial operations of Phase II (additional 150
     megawatts) commenced in the fourth quarter of 2000 and Phase
     III (additional 180 megawatts) is expected to commence in
     early 2002.  As an additional part of this project, Enron is
     constructing an approximately 385-mile, 18-inch natural gas
     pipeline connecting to the Bolivia to Brazil pipeline in
     Bolivia.

  *    An interest in the Rio de Janeiro municipal gas
     distribution company, the gas distribution company of the
     State of Rio de Janeiro and natural gas distribution systems
     in seven other Brazilian states.

  *    A majority ownership interest in Elektro-Electricidade
     e Servicos S.A. ("Elektro").  Elektro has a 51,000-mile
     transmission system for the distribution of electricity to
     approximately 1.5 million consumers throughout 228
     municipalities in the State of Sao Paulo, and a number of
     other municipalities in the State of Mato Grosso do Sul,
     Brazil.

  *    A 97% interest in Vengas, the leading natural gas
     liquids transportation and distribution business in
     Venezuela.  Through Vengas, Enron also has an interest in an
     electric distribution company which services approximately
     50,000 customers in the municipality of Puerto Cabello on
     the northern coast of Venezuela.

  *    A 49.5% interest in a project in northeastern Venezuela
     which will include natural gas liquids extraction,
     fractionation, storage and refrigeration facilities.  The
     facilities, which are located in Santa Barbara, San Joaquin,
     and Jose, are expected to be completed in mid-2001.

  *    A 50% interest in an approximately 357-mile natural gas
     pipeline which runs from the northern coast of Colombia to
     the central region of the country.  Ecopetrol, the state-
     owned gas company of Colombia, is the sole customer for the
     transportation services under a 15-year contract.

  *    A 47.5% interest in a 522-megawatt combined-cycle power
     plant, including a liquefied natural gas terminal and
     desalination facility, in Penuelas, Puerto Rico.  The power
     plant has a 22-year power purchase agreement with the Puerto
     Rico Electric Power Authority.

  *    A natural gas distribution system in Puerto Rico, and
     liquid fuels businesses in both Puerto Rico and Jamaica.

  *    Operates and owns an 80% economic interest in a 185-
     megawatt barge-mounted combined-cycle power plant at Puerto
     Plata on the north coast of the Dominican Republic.  The
     power plant has a 19-year power purchase agreement.

  *    A 37.5% interest in an approximately 234-megawatt fuel-
     oil-fired diesel engine power plant mounted on movable
     barges at Puerto Quetzal on Guatemala's Pacific Coast.
     Approximately 124-megawatts of capacity services the current
     power purchase agreement and the remaining capacity will be
     sold in merchant markets in Guatemala and El Salvador.

  *    A 35% interest in the 70-megawatt power plant mounted
     on movable barges located at the Port of Corinto, Nicaragua.
     The plant supplies 50 megawatts of capacity under a power
     purchase agreement, and the remaining capacity is sold in
     the merchant market.

  *    A 51% interest in the 355-megawatt Bahia Las Minas
     power plant near Colon, Panama.  Plant capacity is sold to
     local distribution companies through five-year power
     purchase agreements.

  *    A 50% interest in an approximately 80-megawatt baseload
     diesel power plant located in Piti, Guam.  The power plant
     has a 20-year power purchase agreement.

  *    Interests in two power plants in the Philippines.  The
     Batangas power project, owned 100% by Enron, is an
     approximately 110-megawatt fuel-oil-fired diesel engine
     plant located at Pinamucan, Batangas, on Luzon Island.  The
     Batangas plant sells power under a 10-year power purchase
     agreement.  The Subic Bay power project, owned 50% by Enron,
     is an approximately 116-megawatt fuel-oil-fired diesel
     engine plant located at the Subic Bay Freeport complex on
     Luzon Island.  The Subic plant has a 15-year power purchase
     agreement.

  *    A 51% interest in a 359-megawatt coal fired combined-
     cycle plant located in Chengdu, China.  The power plant
     sells power under a 20-year power purchase agreement.

  *    A 100% interest in an approximately 160-megawatt diesel
     combined-cycle power plant on Hainan Island, a special
     economic trade zone off the southeastern coast of China.

  *    A 50% interest in a joint venture in Korea which has
     ownership interests in 14 companies primarily engaged in the
     distribution of natural gas liquids.


                   RETAIL ENERGY SERVICES

     Enron Energy Services ("Energy Services") is a provider
of energy outsourcing products and services to business
customers.  This includes sales of natural gas, electricity,
liquids and other commodities and the provision of energy
management services directly to commercial and industrial
customers located in North America and Europe.  Energy
Services provides end-users with a broad range of energy
products and services to reduce total energy costs or to
minimize risks.  These products and services include
delivery of natural gas and electricity, energy tariff and
information management, demand-side services to reduce
energy consumption, and financial services, including price
risk management.

     Energy Services' products and services help commercial
and industrial businesses maximize total energy savings
while meeting their operational needs.  With a focus on
total energy savings and nationwide commodity, services and
finance capabilities, Energy Services provides outsourcing
and other innovative programs not only to supply electricity
and natural gas to businesses, but also to manage
unregulated energy assets to reduce their energy
consumption, delivery and billing costs, to eliminate
inefficiencies of decentralized systems, to reduce energy
demand, and to minimize the risk of energy prices and
operations to the customer.

     Enron is extending its retail products to Europe.
During 2000, significant growth was experienced in marketing
commodity services to medium-sized businesses.  At the end
of 2000, Enron had approximately 130,000 customers in the
United Kingdom.  Enron plans to expand this business model
to other European countries.

                     BROADBAND SERVICES

     During 2000 Enron Broadband Services substantially
completed the Enron Intelligent Network ("EIN"), a high
capacity, global fiber optic network which through pooling
points can switch capacity from one independent network to
another and create scaleability.  Enron Broadband Services
provides:(i) bandwidth management and intermediation
services, and (ii) high quality content delivery services.

     The EIN consists of a high capacity fiber-optic network
based on ownership or contractual access to approximately
18,000 miles of fiber optic network capacity throughout the
United States. At December 31, 2000, the EIN included 25
pooling points of which 18 were in the U.S. and one each in
Tokyo, London, Brussels, Amsterdam, Paris, Dusseldorf and
Frankfurt, allowing the EIN to connect to most major U.S.
cities and a large number in Europe. The breadth of pooling
points within the EIN extends its reach by allowing
connectivity with a greater number of network and service
providers. Enron anticipates further increasing the scope
and reach of the EIN by adding pooling points during 2001.

     The EIN's fiber network and imbedded software
intelligence bypasses traditional fragmented and congested
public internet routes to deliver faster, higher quality
data.  Enron's Broadband Operating System provides the
intelligence to the EIN and connects to both physical and
software network elements. Enron's broadband operating
system enables the EIN to: (i) provision bandwidth in real
time; (ii) control quality and access to the network for
internet service providers; and (iii) control and monitor
applications as they stream over the network to ensure
quality and avoid congested routes. Enron's broadband
operating system automates the transaction process from the
order's inception to electronic billing and funds transfer.
As a result, the EIN allows Enron to provide high quality
content delivery services for content providers and to
contract for firm bandwidth delivery commitments to support
Enron's bandwidth intermediation business.

     Similar to its wholesale energy businesses, Enron acts
as principal in its bandwidth transactions and makes markets
for bandwidth capacity.  Enron provides bandwidth on demand
at specified service levels and guaranteed delivery.  Enron
aggregates bandwidth supplies from multiple counterparties
and, from its portfolio of bandwidth contracts, provides
flexible, low cost bandwidth management products to its
customers.  Enron believes that customers will be able to
reduce costs by paying for only the bandwidth they use, at
prices that reflect the current market. Enron completed the
first bandwidth transaction in December 1999, a monthly
incremental contract for bandwidth between New York City and
Los Angeles. Enron entered into over 300 intermediation
transactions during 2000.  Enron's plans for the bandwidth
capacity markets include risk management products,
structured finance and bandwidth portfolio management. In
addition to bandwidth, Enron is developing markets and
managing risk for all elements of networks, including dark
fiber, circuit transactions, internet transit, private
transport and storage.

     Enron believes that applying its skills developed in
the merchant energy services market to the developing
bandwidth market can result in operating efficiencies to
participants in this market.  Development of bandwidth and
other related products as commodities will be dependent,
among other things, on the ability of the industry to
develop and measure quality of service benchmarks and
connectivity of networks of market participants to
facilitate processing of contracted services.  There can be
no assurance that such a market will develop.

     Enron provides premium broadband delivery services for
media and entertainment, financial services, general
enterprise and technology companies.  The transportation of
media-rich content, including live and on-demand streaming
video, over the EIN significantly enhances the quality and
speed to end-users from that provided by the public
internet.  Enron focused its efforts in 2000 on the
development of a broadband entertainment-on-demand platform
to service the anticipated growing demand for interactive
entertainment services to the consumer.  Enron is pursuing
opportunities related to the commercial and technical
entertainment on demand model developed during 2000.  There
can be no assurance that a broad market will develop for
premium broadband delivery services.

                   OTHER ENRON BUSINESSES

     Azurix Corp. is a global water company engaged in the
business of owning, operating and managing water and
wastewater assets, providing water and wastewater related
services and developing and managing water resources.  Until
March 2001, Enron owned a 50% voting interest in Atlantic
Water Trust, which owned approximately 67% of Azurix common
stock, with public stockholders owning the remainder.  On
March 16, 2001, Azurix shareholders voted to approve and
adopt the Agreement and Plan of Merger by and among Enron
Corp., an Enron subsidiary, and Azurix dated as of December
15, 2000.  As a result of the merger, the Enron subsidiary
merged into Azurix with Azurix being the surviving
corporation.  Under the Agreement and Plan of Merger, each
issued and outstanding share of Azurix common stock, other
than those shares held by Atlantic Water Trust, Enron,
Azurix and any of their wholly owned subsidiaries, was
canceled and converted into the right to receive $8.375 per
share.  Azurix's largest asset is Wessex Water Ltd, a water
and wastewater company based in southwestern England.  Other
assets include a 30-year water and wastewater concession in
the Province of Buenos Aires, Argentina and interests in
long-term water and wastewater concessions in the Province
of Mendoza, Argentina and in Cancun, Mexico.

     Enron is pursuing clean energy solutions in North
America and Europe through Enron Wind Corp.  Enron Wind
Corp. is an integrated manufacturer and developer of wind
power, providing power plant design and engineering, project
development, and operations and maintenance services.  Enron
Wind also designs and manufactures wind turbines in
California and Germany.


                           REGULATION

General

     Enron's interstate natural gas pipeline companies are
subject to the regulatory jurisdiction of the FERC under the
Natural Gas Act ("NGA") with respect to rates, accounts and
records, the addition of facilities, the extension of
services in some cases, the abandonment of services and
facilities, the curtailment of gas deliveries and other
matters.  Enron's intrastate pipeline companies are subject
to state and some federal regulation.  Enron's importation
of natural gas from Canada is subject to approval by the
Office of Fossil Energy of the Department of Energy ("DOE").
Certain activities of Enron are subject to the Natural Gas
Policy Act of 1978 ("NGPA").  Enron's pipelines which carry
natural gas liquids and refined petroleum products are
subject to the regulatory jurisdiction of the FERC under the
Interstate Commerce Act as to rates and conditions of
service.

     Enron's power marketing companies are subject to the
FERC's regulatory jurisdiction under the Federal Power Act
("FPA") with respect to rates, terms and conditions of
service and certain reporting requirements.  Certain of the
power marketing companies' exports of electricity are
subject to approval by the DOE.  Enron's affiliates involved
in cogeneration and independent power production are subject
to regulation by the FERC under the Public Utility
Regulatory Policies Act ("PURPA") and the FPA with respect
to rates, the procurement and provision of certain services
and operating standards.

     The regulatory structure that has historically applied
to the natural gas and electric industry is in transition.
Legislative and regulatory initiatives, at both federal and
state levels, are designed to supplement regulation with
increasing competition.  Legislation to restructure the
electric industry is under active consideration on both the
federal and state levels.  Proposed federal legislation
would make the electric industry more competitive by
providing retail electric customers with the right to choose
their power suppliers.  Modifications to PURPA and the
Public Utility Holding Company Act of 1935 ("PUHCA") have
also been proposed.  In addition, new technology and
interest in self-generation and cogeneration have provided
opportunities for alternative sources and supplies of
energy.  Retention of existing customers and potential
growth of Enron's customer base will depend, in part, upon
the ability of Enron to respond to new customer expectations
and changing economic and regulatory conditions.

     Various federal, state and local laws and regulations
covering the discharge of materials into the environment, or
otherwise relating to the protection of the environment, may
affect Enron's operations and costs through their effect on
the construction, operation and maintenance of pipeline and
terminaling facilities.  It is not anticipated that Enron
will be required in the near future to expend amounts that
are material in relation to its total capital expenditures
program by reason of environmental laws and regulations, but
inasmuch as such laws and regulations are frequently
changed, Enron is unable to predict the ultimate cost of
compliance.

     Enron's international operations are subject to the
jurisdiction of numerous governmental agencies in the
countries in which its projects are located, with respect to
environmental and other regulatory matters.  Generally, many
of the countries in which Enron does and will do business
have recently developed or are in the process of developing
new regulatory and legal structures to accommodate private
and foreign-owned businesses.  These regulatory and legal
structures and their interpretation and application by
administrative agencies are relatively new and sometimes
limited.  Many detailed rules and procedures are yet to be
issued.  The interpretation of existing rules can also be
expected to evolve over time.  Although Enron believes that
its operations are in compliance in all material respects
with all applicable environmental laws and regulations in
the applicable foreign jurisdictions, Enron also believes
that the operations of its projects eventually may be
required to meet standards that are comparable in many
respects to those in effect in the United States and in
countries within the European Community.  In addition, as
Enron acquires additional projects in various countries, it
will be affected by the environmental and other regulatory
restrictions of such countries.

Natural Gas Rates and Regulations

     Northern, Transwestern, Florida Gas and Northern Border
are "natural gas companies" under the NGA and, as such, are
subject to the jurisdiction of the FERC.  The FERC has
jurisdiction over, among other things, the construction and
operation of pipeline and related facilities used in the
transportation and storage and sale of natural gas in
interstate commerce, including the extension, expansion or
abandonment of such facilities.  The FERC also has
jurisdiction over the rates and charges for the
transportation of natural gas in interstate commerce and the
sale by a natural gas company of natural gas in interstate
commerce for resale.  Northern, Transwestern, Florida Gas
and Northern Border hold the required certificates of public
convenience and necessity issued by the FERC authorizing
them to construct and operate all of their pipelines,
facilities and properties for which certificates are
required in order to transport and sell natural gas for
resale in interstate commerce.

     As necessary, Northern, Transwestern, Florida Gas and
Northern Border file applications with the FERC for changes
in their rates and charges designed to allow them to recover
substantially all their costs of providing service to
transportation customers, including a reasonable rate of
return.  These rates are normally allowed to become
effective after a suspension period, and in certain cases
are subject to refund under applicable law, until such time
as the FERC issues an order on the allowable level of rates.

     Under current FERC rate design policy, pipelines are
permitted to recover in the demand component of their rates
all fixed costs, including income taxes and return on
equity, allocated to firm customers.  Since a pipeline
recovers demand costs regardless of whether gas is ever
transported, the straight fixed variable rate design has
reduced the volatility of the revenue stream to pipelines.

     The FERC's Order No. 637 (issued February 9, 2000),
among other things, imposes additional reporting
requirements, requires changes to make pipeline and
secondary market services more comparable, removes the price
caps on secondary market capacity for a period of two years,
allows rates to be based on seasonal or term differentiated
factors and narrows the applicability of the regulatory
right of first refusal to apply only to maximum rate
contracts.  Enron believes that, overall, this lesser
regulation of the secondary market will have a positive
effect on the pipelines and on the industry in general.

     The rates at which natural gas is sold in Texas to gas
utilities serving customers within an incorporated area are
subject to the original jurisdiction of the Railroad
Commission of Texas.  The rates set by city councils or
commissions for gas sold within their jurisdiction may be
appealed to the Railroad Commission.  Regulation of
intrastate gas sales and transportation by the Railroad
Commission is governed by certain provisions of the Texas
Gas Utility Regulatory Act of 1983.  The Railroad Commission
also regulates production activities and to some degree the
operation of affiliated special marketing programs.

Electric Industry Regulation

     Historically, the electric industry has been subject to
comprehensive regulation at the federal and state levels.
The FERC regulated sales of electric power at wholesale and
the transmission of electric energy in interstate commerce
pursuant to the FPA.  The FERC subjected public utilities
under the FPA to rate and tariff regulation, accounting and
reporting requirements, as well as oversight of mergers and
acquisitions, securities issuances and dispositions of
facilities.  States or local authorities have historically
regulated the distribution and retail sale of electricity,
as well as the construction of generating facilities.

     Enacted in 1978, PURPA created opportunities for
independent power producers, including cogenerators.  If a
generating project obtained the status of a "Qualifying
Facility," it was exempted by PURPA from most provisions of
the FPA and certain state laws relating to securities, rate
and financial regulation.  PURPA also required electric
utilities (i) to purchase electricity generated by
Qualifying Facilities at a price based on the utility's
avoided cost of purchasing electricity or generating
electricity itself, and (ii) to sell supplementary, back-up,
maintenance and interruptible power to Qualifying Facilities
on a just and reasonable and non-discriminatory basis.

     PUHCA subjects certain entities that directly or
indirectly own, control or hold the power to vote 10% of the
outstanding voting securities of a "public utility company"
or a company which is a "holding company" of a public
utility company to registration requirements of the
Securities and Exchange Commission ("SEC") and regulation
under PUHCA, unless the entity is eligible for an exemption
or has been granted an SEC order declaring the entity not to
be a holding company.  Affiliates, or direct or indirect
holders of 5% of the voting securities of such companies,
are also subject to regulation under PUHCA unless so
eligible for an exemption or SEC order.  PUHCA requires
registration for a holding company of a public utility
company, and requires a public utility holding company to
limit its operations to a single integrated utility system
and to divest any other operations not functionally related
to the operation of the utility system.  A public utility
company which is a subsidiary of a registered holding
company under PUHCA is subject to financial and
organizational regulation, including SEC approval of its
financing transactions.

     The Energy Policy Act of 1992 ("EP Act") exempted from
some traditional federal utility regulation generators
selling power at wholesale in an effort to enhance
competition in the wholesale generation market.  The EP Act
also authorized FERC to require utilities to transport and
deliver or "wheel" energy for the supply of bulk power to
wholesale customers.

     In April 1996, FERC paved the way for the transition to
more competitive electric markets by issuing its Order Nos.
888 and 889.  Order No. 888 required utilities to provide
third parties wholesale open access to transmission
facilities on terms comparable to those that apply when
utilities use their own systems.  Utilities were required by
the order to file open access tariffs in July 1996.  Power
pools, which are associations of interconnected electric
transmission and distribution systems that have an agreement
for integrated and coordinated operations, were directed to
file their open access tariffs by the end of 1996.  These
tariffs enable eligible parties to obtain wholesale
transmission service over utilities' transmission systems.
In Order No. 888, FERC stated its intention to permit
utilities to recover legitimate, verifiable and prudently
incurred costs that are rendered uneconomic or "stranded" as
a result of customers taking advantage of wholesale open
access to meet their power needs from others.  In Order No.
889, FERC required utilities owning transmission facilities
to adopt procedures for an open access same-time information
system ("OASIS") that will make available, on a real-time
basis, pertinent information concerning each transmission
utility's services.  The order also promulgated standards of
conduct to ensure that utilities separate their transmission
functions from their wholesale power merchant functions and
to prevent the misuse of commercially valuable information.
In March 1997 FERC issued its orders on rehearing of Order
Nos. 888 and 889.  In these orders FERC upheld the basic
open access and OASIS regulatory framework established in
Order Nos. 888 and 889, while making certain modifications
to its open access and stranded cost recovery rules.

     Congress is considering legislation to modify federal
laws affecting the electric industry.  Bills have been
introduced in the Senate and the House of Representatives
that would, among other things, open wholesale electric
markets to greater competition and/or provide retail
electric customers with the right to choose their power
suppliers.  Modifications to PURPA and PUHCA have also been
proposed.  In addition, various states have either enacted
or are considering legislation designed to deregulate the
production and sale of electricity.  Deregulation is
expected to result in a shift from cost-based rates to
market-based rates for electric energy and related services.
Although the legislation and regulatory initiatives vary,
common themes include the availability of market pricing,
retail customer choice, recovery of stranded costs, and
separation of generation assets from transmission,
distribution and other assets.  It is unclear whether or
when all power customers will obtain open access to power
supplies.  Decisions by regulatory agencies may have a
significant impact on the future economics of the power
marketing business.

     The Oregon Public Utility Commission ("OPUC"), a three-
member commission appointed by the Governor of Oregon,
approves PGE's retail rates and establishes conditions of
utility service.  The OPUC ensures that prices are fair and
equitable and provides PGE an opportunity to earn a fair
return on its investment.  In addition, the OPUC regulates
the issuance of securities and prescribes the system of
accounts to be kept by Oregon utilities.  PGE is also
subject to the jurisdiction of the FERC with regard to the
transmission and sale of wholesale electric energy,
licensing of hydroelectric projects and certain other
matters.  Construction of new generating facilities requires
a permit from Oregon Energy Facility Siting Counsel.

Environmental Regulations

     Enron and its subsidiaries are subject to extensive
federal, state and local laws and regulations covering the
discharge of materials into the environment, or otherwise
relating to the protection of the environment, and which
require expenditures for remediation at various operating
facilities and waste disposal sites, as well as expenditures
in connection with the construction of new facilities.
Enron believes that its operations and facilities are in
general compliance with applicable environmental
regulations.  Environmental laws and regulations have
changed substantially and rapidly over the last 20 years,
and Enron anticipates that there will be continuing changes.
The clear trend in environmental regulation is to place more
restrictions and limitations on activities that may impact
the environment, such as emissions of pollutants, generation
and disposal of wastes and use and handling of chemical
substances.  Increasingly strict environmental restrictions
and limitations have resulted in increased operating costs
for Enron and other businesses throughout the United States,
and it is possible that the costs of compliance with
environmental laws and regulations will continue to
increase.  Enron will attempt to anticipate future
regulatory requirements that might be imposed and to plan
accordingly in order to remain in compliance with changing
environmental laws and regulations and to minimize the costs
of such compliance.

     The Comprehensive Environmental Response, Compensation
and Liability Act ("CERCLA"), also known as the "Superfund"
law, requires payments for cleanup of certain abandoned
waste disposal sites, even though such waste disposal
activities were undertaken in compliance with regulations
applicable at the time of disposal.  Under the Superfund
legislation, one party may, under certain circumstances, be
required to bear more than its proportional share of cleanup
costs at a site where it has responsibility pursuant to the
legislation, if payments cannot be obtained from other
responsible parties.  Other legislation mandates cleanup of
certain wastes at facilities that are currently being
operated.  States also have regulatory programs that can
mandate waste cleanup.  CERCLA authorizes the Environmental
Protection Agency ("EPA") and, in some cases, third parties
to take actions in response to threats to the public health
or the environment and to seek to recover from the
responsible classes of persons the costs they incur.  The
scope of financial liability under these laws involves
inherent uncertainties.  Enron has received requests for
information from the EPA and state agencies concerning what
wastes Enron may have sent to certain sites, and it has also
received requests for contribution from other parties with
respect to the cleanup of other sites.  However, management
does not believe that any costs that may be incurred in
connection with these sites (either individually or in the
aggregate) will have a material impact on Enron's financial
position or results of operations.  (See Item 3, "Legal
Proceedings").

     PGE's current and historical operations are subject to
a wide range of environmental protection laws covering air
and water quality, noise, waste disposal, and other
environmental issues.  PGE is also subject to the Federal
Rivers and Harbors Act of 1899 and similar Oregon laws under
which it must obtain permits from the U.S. Army Corps of
Engineers or the Oregon Division of State Lands to construct
facilities or perform activities in navigable waters of the
State.  State agencies or departments which have direct
jurisdiction over environmental matters include the
Environmental Quality Commission, the Oregon Department of
Environmental Quality, the Oregon Office of Energy and
Oregon Energy Facility Siting Counsel.  Environmental
matters regulated by these agencies include the siting and
operation of generating facilities and the accumulation,
cleanup and disposal of toxic and hazardous wastes.

Water Industry Regulation

     In the United States, the rates for water and
wastewater services are generally subject to state and local
laws and regulation.  The Safe Drinking Water Act directs
the EPA to set drinking water standards for the community
water supply systems in the United States.  The Federal
Water Pollution Control Act (the "Clean Water Act")
establishes a system of standards, permits and enforcement
procedures for the discharge of pollutants from industrial
and municipal wastewater sources.  The law requires permits
for discharges from water treatment facilities and sets
treatment standards for industries and wastewater treatment
plants.  Discharge permits issued under the Clean Water Act
are subject to renewal once every five years.  The economic
aspects of the water industry in England and Wales is
principally regulated under the provisions of the Water Act
1989, the Water Industry Act 1991 (which consolidated the
Water Act 1989) and the Water Resources Act 1991.  In
general, most countries where Azurix has invested (including
Canada, Argentina, Brazil and Mexico), or intends to
consider investments, have drinking water quality and
environmental laws and regulations.

Other

     PGE is a 67.5% owner of the Trojan Nuclear Plant
("Trojan").  The Nuclear Regulatory Commission ("NRC")
regulates the licensing and decommissioning of nuclear power
plants.  In 1993 the NRC issued a possession-only license
amendment to PGE's Trojan operating license and in early
1996 approved the Trojan Decommissioning Plan.  Approval of
the Trojan Decommissioning Plan by the NRC and Oregon Energy
Facility Siting Counsel has allowed PGE to commence
decommissioning activities, which are proceeding
satisfactorily and within approved cost estimates.  After
receiving regulatory approval, PGE in 1999 shipped and
disposed of the Trojan reactor vessel as a single package
called the Reactor Vessel and Internals Removal Project.
Equipment removal and disposal activities continued in 2000.
Trojan will be subject to NRC regulation until Trojan is
fully decommissioned, all nuclear fuel is removed from the
site and the license is terminated.  The Oregon Department
of Energy also monitors Trojan.

<PAGE>

        CURRENT EXECUTIVE OFFICERS OF THE REGISTRANT


    Name and Age      Present Principal Position and Other
                      Material Positions Held During Last
                      Five Years


Kenneth L. Lay (58)   Chairman of the Board, Enron Corp.,
                      since February 1986.  Chief Executive
                      Officer, Enron Corp., from February
                      1986 to February 2001.

Jeffrey K. Skilling (47) President and Chief Executive
                      Officer since February 2001.
                      President and Chief Operating Officer,
                      Enron Corp., from January 1997 to
                      February 2001.  Chief Executive
                      Officer and Managing Director of Enron
                      Capital & Trade Resources Corp.
                      ("ECT") from June 1995 to December
                      1996.  From August 1990 to June 1995,
                      Mr. Skilling served ECT in a variety
                      of executive managerial positions.

J. Clifford Baxter (42)  Vice Chairman, Enron Corp., since
                      October 2000 and Chief Strategy
                      Officer since June 2000. Chairman and
                      Chief Executive Officer, Enron North
                      America Corp., from June 1999 until
                      June 2000. Senior Vice President,
                      Corporate Development, Enron Corp.,
                      from January 1997 until June 1999.
                      Managing Director, ECT, 1996; Vice
                      President, Corporate Development, ECT,
                      1995-1996.

Mark A. Frevert (46)  Chairman and Chief Executive Officer,
                      Enron Wholesale Services, since
                      June 2000.  Chairman and Chief
                      Executive Officer of Enron Europe from
                      March 1997 to June 2000.  From 1993
                      to March 1997, Mr. Frevert served ECT
                      in a variety of executive managerial
                      positions.

Stanley C. Horton (51)  Chairman and Chief Executive
                      Officer, Enron Transportation
                      Services, since January 1997.  Co-
                      Chairman and Chief Executive Officer
                      of Enron Operations Corp. from
                      February 1996 to January 1997.
                      President and Chief Operating Officer
                      of Enron Operations Corp. from June
                      1993 to February 1996.

Lou L. Pai (53)       Chairman and Chief Executive Officer,
                      Enron Accelerator, since February 2001.
                      Chairman of the Board and Chief
                      Executive Officer of Enron Energy
                      Services from March 1997 until
                      February 2001.  President and Chief
                      Operating Officer of ECT from August
                      1995 to March 1997.  From March 1993
                      to August 1995, Mr. Pai served ECT in
                      a variety of executive managerial
                      positions.

Kenneth D. Rice (42)  Chairman and Chief Executive
                      Officer, Enron Broadband Services,
                      Inc., since June 2000.  Chief Commercial
                      Officer, Enron Broadband Services, Inc.,
                      from June 1999 until June 2000.   Chairman
                      and Chief Executive Officer of ECT - North
                      America from March 1997 until June
                      1999.  From 1993 to March 1997, Mr.
                      Rice served ECT in a variety of
                      executive managerial positions.


Richard B. Buy (48)   Executive Vice President and Chief
                      Risk Officer, Enron Corp., since July
                      1999.  Senior Vice President and Chief
                      Risk Officer, Enron Corp., from March
                      1999 until July 1999.  Managing
                      Director and Chief Risk Officer, ECT,
                      from January 1998 to March 1999.  Vice
                      President and Chief Credit Officer,
                      ECT, from August 1995 to January 1998.

Richard A. Causey (41)  Executive Vice President and
                      Chief Accounting Officer, Enron Corp.,
                      since July 1999.  Senior Vice
                      President and Chief Accounting and
                      Information Officer, Enron Corp., from
                      January 1997 to July 1999.  Managing
                      Director, ECT, from June 1996 to
                      January 1997; Vice President, ECT,
                      from January 1992 to June 1996.

James V. Derrick, Jr.(56) Executive Vice President and
                      General Counsel, Enron Corp., since
                      July 1999.  Senior Vice President and
                      General Counsel, Enron Corp., from
                      June 1991 to July 1999.  Partner,
                      Vinson & Elkins from January 1977
                      until June 1991.

Andrew S. Fastow (39) Executive Vice President and Chief
                      Financial Officer, Enron Corp., since
                      July 1999.  Senior Vice President and
                      Chief Financial Officer from March
                      1998 to July 1999.  Senior Vice
                      President, Finance, Enron Corp., from
                      January 1997 to March 1998.  Managing
                      Director, Retail and Treasury, ECT,
                      from May 1995 to January 1997.  Vice
                      President, ECT, from January 1993 to
                      May 1995.

Steven J. Kean (39)  Executive Vice President and Chief of
                     Staff, Enron Corp. since July 1999.
                     Senior Vice President, Government
                     Affairs, Enron Corp., from 1997 to
                     1999.  From 1989 to 1997, Mr. Kean
                     held a variety of management positions
                     in Enron Corp. subsidiaries.

Mark E. Koenig (45)  Executive Vice President, Investor
                     Relations, Enron Corp., since July
                     1999.  Senior Vice President, Investor
                     Relations, Enron Corp., from July 1997
                     until July 1999.  Vice President,
                     Investor Relations, Enron Corp., from
                     December 1992 until July 1997.

J. Mark Metts (42)   Executive Vice President, Corporate
                     Development, Enron Corp., since August
                     1999.  Partner, Vinson & Elkins L.L.P.
                     from January 1991 until August 1999.

Item 2.  PROPERTIES

Natural Gas Transmission

     Enron's domestic natural gas facilities include
approximately 25,000 miles of pipelines, four underground
gas storage fields and two liquefied natural gas storage
facilities.  Enron also owns interests in pipeline and
related facilities associated with its participation and
investments in jointly-owned pipeline systems.

     Substantially all the transmission lines of Enron are
constructed on rights-of-way granted by the apparent record
owners of such property.  In many instances, lands over
which rights-of-way have been obtained are subject to prior
liens which have not been subordinated to the right-of-way
grants.  In some cases, not all of the apparent record
owners have joined in the right-of-way grants, but in
substantially all such cases, signatures of the owners of
majority interests have been obtained.  Permits have been
obtained from public authorities to cross over or under, or
to lay facilities in or along, water courses, county roads,
municipal streets and state highways, and in some instances,
such permits are revocable at the election of the grantor,
or, the pipeline may be required to move its facilities at
its own expense.  Permits have also been obtained from
railroad companies to cross over or under lands or rights-of-
way, many of which are also revocable at the grantor's
election.  Some such permits require annual or other
periodic payments.  In a few minor cases, property for
pipeline purposes was purchased in fee.

     In most cases, Enron's transmission subsidiaries have
the right of eminent domain to acquire rights-of-way and
lands necessary for their pipelines and appurtenant
facilities.

     Enron's regulator and compressor stations and offices
are located on tracts of land owned by it in fee or leased
from others.

     Enron is of the opinion that it has generally
satisfactory title to its rights-of-way and lands used in
the conduct of its businesses, subject to liens for current
taxes, liens incident to operating agreements and minor
encumbrances, easements and restrictions which do not
materially detract from the value of such property or the
interest of Enron therein or the use of such properties in
such businesses.

Electric Utility Properties

     PGE's principal plants and appurtenant generating
facilities and storage reservoirs are situated on land owned
by PGE in fee or land under the control of PGE pursuant to
valid existing leases, federal or state licenses, easements,
or other agreements.  In some cases meters and transformers
are located upon the premises of customers.  The indenture
securing PGE's first mortgage bonds constitutes a direct
first mortgage lien on substantially all utility property
and franchises, other than expressly excepted property.

     Generating facilities owned by PGE are set forth in the
following table:
                                                   PGE Net
                                                      MW
    Facility        Location            Fuel      Capability
 Wholly Owned:
   Faraday         Estacada, OR          Hydro         44
   North Fork      Estacada, OR          Hydro         54
   Oak Grove       Three Lynx, OR        Hydro         44
   River Mill      Estacada, OR          Hydro         25
   Pelton          Madras, OR            Hydro        110
   Round Butte     Madras, OR            Hydro        300
   Bull Run        Bull Run, OR          Hydro         22
   Sullivan        West Linn, OR         Hydro         16
   Beaver          Clatskanie, OR        Gas/Oil      500
   Coyote Springs  Boardman, OR          Gas/Oil      242

Jointly Owned:
   Boardman        Boardman, OR          Coal         362
   Colstrip 3 & 4  Colstrip, MT          Coal         296
                              TOTAL                 2,015


     PGE holds licenses under the Federal Power Act for its
hydroelectric generating plants as well as licenses from the
State of Oregon for all or portions of five of the plants.
All of its licenses expire during the years 2001 to 2006.
The FERC requires that a notice of intent to relicense these
projects be filed approximately five years prior to
expiration of the license.

     Following the 1993 closure of the Trojan nuclear plant,
PGE was granted a possession-only license amendment by the
NRC.  In early 1996 PGE received NRC approval of its Trojan
decommissioning plan.

     PGE leases its headquarters complex in downtown
Portland and the coal-handling facilities and certain
railroad cars for the Boardman coal plant.

Domestic Power Plants

     Enron's principal domestic operating power plants and
appurtenant facilities are situated on land owned by Enron
(or joint ventures in which Enron has an ownership interest)
in fee or land under the control of Enron (or such joint
ventures) pursuant to valid existing leases, licenses,
easements or other agreements.  Power plants in which Enron
owns various interests are set forth in the following table:


Facility              Location      Fuel         Size/Capacity

Brownsville Power I,  Brownsville,  Natural gas        500 MW
LLC                   TN
Caledonia Power I,    Caledonia,    Natural gas        450 MW
LLC                   MS
New Albany Power I,   New Albany,   Natural gas        390 MW
LLC                   MS
Las Vegas             Las Vegas,    Natural gas         53 MW
Cogeneration          NV
Des Plaines Green     Manhattan,    Natural gas        650 MW
Land Development      IL
LLC
Gleason Power I, LLC  Gleason, TN   Natural gas        544 MW
West Fork Land        Wheatland,    Natural gas        514 MW
Development           IN
Company LLC
Pastoria Energy       Pastoria, CA  Natural gas        750 MW
Facility*
Doyle LLC             Monrose, GA   Natural gas        342 MW

*In development

International Power Plants, Pipelines and Electric
Utility Properties

     Enron's principal international operating power plants,
pipelines and electric utility properties and appurtenant
facilities are (i) situated on land owned by Enron
(or joint ventures in which Enron has an ownership
interest) in fee or land under the control of
Enron (or such joint ventures) pursuant to valid existing
leases, licenses, easements or other agreements, or (ii) in
the case of certain power plants, barge-mounted on vessels
owned by Enron (or such joint ventures).  Power plants and
pipelines in which Enron owns various interests are set
forth in the following table:


Facility             Location     Fuel     Size/Capacity

Power Plants:
Trakya               Turkey        Gas        478 MW
Dabhol, Phase I      India         Gas        826 MW
Cuiaba, Phases I &   Brazil        Diesel     300 MW
II
Puerto Plata         Dominican     Fuel oil   185 MW
                     Republic
Puerto Quetzal       Guatemala     Fuel oil   234 MW
Corinto              Nicaragua     Fuel oil    70 MW
Ecoelectrica         Puerto Rico   LNG        522 MW
Bahia Las Minas      Panama        Diesel     355 MW
Piti                 Guam          Diesel      80 MW
Batangas             Philippines   Fuel oil   110 MW
Subic Bay            Philippines   Fuel oil   116 MW
Hainan Island        China         Diesel     160 MW
Chengdu              China         Coal       359 MW

Pipelines:
TGS                  Argentina       -      1.9 Bcf/d;
                                           4,104 miles
Centragas            Colombia        -     110 MMcf/d;
                                            357 miles
Transredes           Bolivia         -      4.3 Bcf/d;
                                             57 MMb/d;
                                           3,570 miles
BBPL (Bolivia to     Bolivia and     -      1.06 Bcf/d
Brazil pipeline)     Brazil                1,969 miles

Electric Utility Properties
Elektro              Brazil          -     51,000 mile
                                           tranmission system


Item 3.  LEGAL PROCEEDINGS

     Enron is a party to various claims and litigation, the
significant items of which are discussed below.  Although
no assurances can be given, Enron believes, based on its
experience to date and after considering appropriate
reserves that have been established, that the ultimate
resolution of such items, individually or in the aggregate,
will not have a materially adverse impact on Enron's
financial position or its results of operations.

     Litigation.  In 1995, several parties (the Plaintiffs)
filed suit in Harris County District Court in Houston,
Texas, against Intratex Gas Company (Intratex), Houston Pipe
Line Company and Panhandle Gas Company (collectively, the
Enron Defendants), each of which is a wholly-owned
subsidiary of Enron.  The Plaintiffs were either sellers or
royalty owners under numerous gas purchase contracts with
Intratex, many of which have terminated.  Early in 1996, the
case was severed by the Court into two matters to be tried
(or otherwise resolved) separately.  In the first matter,
the Plaintiffs alleged that the Enron Defendants committed
fraud and negligent misrepresentation in connection with the
"Panhandle program," a special marketing program established
in the early 1980s.  This case was tried in October 1996 and
resulted in a verdict for the Enron Defendants.  In the
second matter, the Plaintiffs allege that the Enron
Defendants violated state regulatory requirements and
certain gas purchase contracts by failing to take the
Plaintiffs' gas ratably with other producers' gas at certain
times between 1978 and 1988.  The trial court certified a
class action with respect to ratability claims.  On March 9,
2000, the Texas Supreme Court ruled that the trial court's
class certification was improper and remanded the case to
the trial court.  The Enron Defendants deny the Plaintiffs'
claims and have asserted various affirmative defenses,
including the statute of limitations.  The Enron Defendants
believe that they have strong legal and factual defenses,
and intend to vigorously contest the claims.  Although no
assurances can be given, Enron believes that the ultimate
resolution of these matters will not have a materially
adverse effect on its financial position or results of
operations.

     On November 21, 1996, an explosion occurred in or
around the Humerto Vidal Building in San Juan, Puerto Rico.
The explosion resulted in fatalities, bodily injuries and
damage to the building and surrounding property.  San Juan
Gas Company, Inc. (San Juan), an Enron affiliate, operated a
propane/air distribution system in the vicinity, but did not
provide service to the building.  Enron, San Juan Gas, four
affiliates and their insurance carriers were named as
defendants, along with several third parties, including The
Puerto Rico Aqueduct and Sewer Authority, Puerto Rico
Telephone Company, Heath Consultants Incorporated, Humberto
Vidal, Inc. and their insurance carriers, in numerous
lawsuits filed in U.S. District Court for the District of
Puerto Rico and the Superior Court of Puerto Rico.  These
suits seek damages for wrongful death, personal injury,
business interruption and property damage allegedly caused
by the explosion.  After nearly four years without
determining the cause of the explosion, all parties have
agreed not to litigate further that issue, but to move these
suits toward settlements or trials to determine whether each
plaintiff was injured as a result of the explosion and, if
so, the lawful damages attributable to such injury.  The
defendants have agreed on a fund for settlements or final
awards.  Numerous claims have been settled.  Although no
assurances can be given, Enron believes that the ultimate
resolution of these matters will not have a materially
adverse effect on its financial position or results of
operations.

     Trojan Investment Recovery.  In early 1993, PGE ceased
commercial operation of the Trojan nuclear power generating
facility.  The OPUC granted PGE, through a general rate
order, recovery of, and a return on, 87% of its remaining
investment in Trojan.

     The OPUC's general rate order related to Trojan has
been subject to litigation in various state courts,
including rulings by the Oregon Court of Appeals and
petitions to the Oregon Supreme Court filed by parties
opposed to the OPUC's order, including the Utility Reform
Project (URP) and the Citizens Utility Board (CUB).

     In August 2000, PGE entered into agreements with CUB
and the staff of the OPUC to settle the litigation related
to PGE's recovery of its investment in the Trojan plant.
Under the agreements, CUB agreed to withdraw from the
litigation and to support the settlement as the means to
resolve the Trojan litigation.  The OPUC approved the
accounting and ratemaking elements of the settlement on
September 29, 2000.  As a result of these approvals, PGE's
investment in Trojan is no longer included in rates charged
to customers, either through a return on or a return of that
investment.  Collection of ongoing decommissioning costs at
Trojan is not affected by the settlement agreements or the
September 29, 2000 OPUC order.  With CUB's withdrawal, URP
is the one remaining significant adverse party in the
litigation.  URP has indicated that it plans to continue to
challenge the OPUC order allowing PGE recovery of its
investment in Trojan.

     Enron cannot predict the outcome of these actions.
Although no assurances can be given, Enron believes that the
ultimate resolution of these matters will not have a
material adverse effect on its financial position or results
of operations.

     Environmental Matters.  Enron is subject to extensive
federal, state and local environmental laws and regulations.
These laws and regulations require expenditures in connection
with the construction of new facilities, the operation of
existing facilities and for remediation at various operating
sites.  The implementation of the Clean Air Act Amendments
is expected to result in increased operating expenses.
These increased operating expenses are not expected to have
a materially adverse effect on Enron's financial position
or results of operations.

     Enron's natural gas pipeline companies conduct soil
and groundwater remediation of a number of their
facilities.  Enron does not expect to incur material
expenditures in connection with soil and groundwater
remediation.

     In addition, Enron has received requests for
information from the EPA and state environmental agencies
inquiring whether Enron has disposed of materials at other
waste disposal sites.  Enron has also received requests for
contribution from other parties with respect to the cleanup
of other sites.  Enron may be required to share in the
costs of the cleanup of some of these sites.  However,
based upon the amounts claimed and the nature and volume of
materials sent to sites at which Enron has an interest,
management does not believe that any potential costs
incurred in connection with these notices and third party
claims, either taken individually or in the aggregate, will
have a material impact on Enron's financial position or
results of operations.

Item 4.  SUBMISSION OF MATTERS TO A VOTE OF SECURITY
         HOLDERS

         None.


<PAGE>
                           PART II

Item 5.  MARKET FOR THE REGISTRANT'S COMMON EQUITY AND
         RELATED SHAREHOLDER MATTERS

Common Stock

     The following table indicates the high and low sales
prices for the common stock of Enron as reported on the New
York Stock Exchange (consolidated transactions reporting
system), the principal market in which the securities are
traded, and dividends paid per share for the calendar
quarters indicated.  The common stock is also listed for
trading on the Chicago Stock Exchange and the Pacific Stock
Exchange, as well as The London Stock Exchange and
Frankfurt Stock Exchange.

<TABLE>
<CAPTION>
                              2000                          1999
                   High       Low     Dividends     High     Low  Dividends

<S>                 <C>       <C>      <C>     <C>        <C>       <C>
First Quarter.....  $78 5/8   $41 3/8  $.1250  $35 19/32  $28 3/4   $.1250
Second Quarter....   78 15/16  62 1/2   .1250   41 15/32   30 1/2    .1250
Third Quarter.....   90 3/4    65 9/16  .1250   44 23/32   38 1/16   .1250
Fourth Quarter....   88 11/16  63 1/2   .1250   44 7/8     34 7/8    .1250
</TABLE>


Cumulative Second Preferred Convertible Stock

     The following table indicates the high and low sales
prices for the Cumulative Second Preferred Convertible
Stock ("Second Preferred Stock") of Enron as reported on
the New York Stock Exchange (consolidated transactions
reporting system), the principal market in which the
securities are traded, and dividends paid per share for the
calendar quarters indicated.  The Second Preferred Stock is
also listed for trading on the Chicago Stock Exchange.

<TABLE>
<CAPTION>
                               2000                          1999
                   High         Low       Dividends    High     Low        Dividends

<S>               <C>         <C>          <C>      <C>         <C>          <C>
First Quarter.... 1,953       1,868 7/8    $3.4130     --       --           $3.4130
Second Quarter... 2,146 3/8   2,118 1/8    $3.4130     --       --            3.4130
Third Quarter....    --          --        $3.4130     --       --            3.4130
Fourth Quarter...    --          --        $3.4130  $1,170 1/8  $1,170 1/8    3.4130
</TABLE>

     At December 31, 2000, there were approximately 58,920
record holders of common stock and 160 record holders of
Second Preferred Stock.

     Other information required by this item is set forth
under Item 6 -- "Selected Financial Data (Unaudited) -
Common Stock Statistics" for the years 1996-2000.

<PAGE>
<TABLE>
ITEM 6.  SELECTED FINANCIAL DATA (UNAUDITED)

<CAPTION>
                                        2000       1999      1998      1997      1996

<S>                                   <C>        <C>       <C>       <C>       <C>
Operating Revenues (millions)         $100,789   $40,112   $31,260   $20,273   $13,289

Total Assets (millions)               $ 65,503   $33,381   $29,350   $22,552   $16,137


Common Stock Statistics(a)
  Income before cumulative effect
   of accounting changes
     Total (millions)                      979     1,024       703       105       584
     Per share - basic                   $1.22     $1.36     $1.07     $0.16     $1.16
     Per share - diluted                 $1.12     $1.27     $1.01     $0.16     $1.08
  Earnings on common stock
     Total (millions)                     $896      $827      $686      $ 88      $568
     Per share - basic                   $1.22     $1.17     $1.07     $0.16     $1.16
     Per share - diluted                 $1.12     $1.10     $1.01     $0.16     $1.08
  Dividends on common stock
     Total (millions)                     $368      $355      $312      $243      $212
     Per share                           $0.50     $0.50     $0.48     $0.46     $0.43
  Shares outstanding (millions)
     Actual at year-end                    752       716       662       622       510
     Average for the year - basic          736       705       642       544       492
     Average for the year - diluted        814       769       695       555       540

Capitalization (millions)
  Short-term and long-term debt        $10,229   $ 8,152   $ 7,357   $ 6,254    $3,349
  Minority interests                     2,414     2,430     2,143     1,147       755
  Company-obligated preferred
   securities of subsidiaries              904     1,000     1,001       993       592
  Shareholders' equity                  11,470     9,570     7,048     5,618     3,723
     Total capitalization              $25,017   $21,152   $17,549   $14,012    $8,419

<FN>
(a)  Share and per share amounts have been restated to
     reflect the two-for-one stock split effective August 13,
     1999.
</TABLE>

<PAGE>
ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND
RESULTS OF OPERATIONS

   The following review of the results of operations and
financial condition of Enron Corp. and its subsidiaries and
affiliates (Enron) should be read in conjunction with the
Consolidated Financial Statements.

RESULTS OF OPERATIONS

Consolidated Net Income
   Enron's net income for 2000 was $979 million compared to $893
million in 1999 and $703 million in 1998.  Items impacting
comparability are discussed in the respective segment results.
Net income before items impacting comparability was $1,266
million, $957 million and $698 million, respectively, in 2000,
1999 and 1998.  Enron's business is divided into five segments
and Exploration and Production (Enron Oil & Gas Company) through
August 16, 1999 (see Note 2 to the Consolidated Financial
Statements).  Enron's operating segments include:

   Transportation and Distribution. Transportation and
Distribution consists of Enron Transportation Services and
Portland General.  Transportation Services includes Enron's
interstate natural gas pipelines, primarily Northern Natural Gas
Company (Northern), Transwestern Pipeline Company (Transwestern),
Enron's 50% interest in Florida Gas Transmission Company (Florida
Gas) and Enron's interests in Northern Border Partners, L.P. and
EOTT Energy Partners, L.P. (EOTT).

   Wholesale Services. Wholesale Services includes Enron's
wholesale businesses around the world.  Wholesale Services
operates in developed markets such as North America and Europe,
as well as developing or newly deregulating markets including
South America, India and Japan.

   Retail Energy Services. Enron, through its subsidiary Enron
Energy Services, LLC (Energy Services), is extending its energy
expertise and capabilities to end-use retail customers in the
industrial and commercial business sectors to manage their energy
requirements and reduce their total energy costs.

   Broadband Services. Enron's broadband services business
(Broadband Services) provides customers with a single source for
broadband services, including bandwidth intermediation and the
delivery of premium content.

   Corporate and Other. Corporate and Other includes Enron's
investment in Azurix Corp. (Azurix), which provides water and wastewater
services, results of Enron Renewable Energy Corp. (EREC), which
develops and constructs wind-generated power projects, and the
operations of Enron's methanol and MTBE plants as well as overall
corporate activities of Enron.

Net income includes the following:

<TABLE>
<CAPTION>
(In millions)                                2000    1999    1998
<S>                                        <C>      <C>     <C>
After-tax results before items impacting
 comparability                             $1,266   $ 957   $ 698

Items impacting comparability:(a)
  Charge to reflect impairment by Azurix     (326)      -       -
  Gain on TNPC, Inc. (The New Power
   Company), net                               39       -       -
  Gains on sales of subsidiary stock            -     345      45
  MTBE-related charges                          -    (278)    (40)
  Cumulative effect of accounting
   changes                                      -    (131)      -
Net income                                 $  979   $ 893   $ 703

<FN>
(a) Tax affected at 35%, except where a specific tax rate
    applied.
</TABLE>

   Diluted earnings per share of common stock were as follows:
<TABLE>
<CAPTION>
                                               2000      1999      1998

<S>                                           <C>       <C>       <C>
Diluted earnings per share(a):
  After-tax results before items
   impacting comparability                    $1.47     $1.18     $1.00

  Items impacting comparability:
     Charge to reflect impairment by Azurix   (0.40)        -         -
     Gain on The New Power Company, net        0.05         -         -
     Gains on sales of subsidiary stock           -      0.45      0.07
     MTBE-related charges                         -     (0.36)    (0.06)
     Cumulative effect of accounting changes      -     (0.17)        -
Diluted earnings per share                    $1.12     $1.10     $1.01

<FN>
(a) Restated to reflect the two-for-one stock split effective
    August 13, 1999.
</TABLE>

Income Before Interest, Minority Interests and Income Taxes
   The following table presents income before interest, minority
interests and income taxes (IBIT) for each of Enron's operating
segments (see Note 20 to the Consolidated Financial Statements):

<TABLE>
<CAPTION>
(In millions)                      2000      1999    1998

<S>                               <C>      <C>      <C>
Transportation and Distribution:
  Transportation Services         $  391   $  380   $  351
  Portland General                   341      305      286
Wholesale Services                 2,260    1,317      968
Retail Energy Services               165      (68)    (119)
Broadband Services                   (60)       -        -
Exploration and Production             -       65      128
Corporate and Other                 (615)      (4)     (32)
  Income before interest,
   minority interests and taxes   $2,482   $1,995   $1,582
</TABLE>

Transportation and Distribution
   Transportation Services.  The following table summarizes total
volumes transported by each of Enron's interstate natural gas
pipelines.

<TABLE>
<CAPTION>
                                        2000    1999    1998

<S>                                     <C>     <C>     <C>
Total volumes transported (BBtu/d)(a)
  Northern Natural Gas                  3,529   3,820   4,098
  Transwestern Pipeline                 1,657   1,462   1,608
  Florida Gas Transmission              1,501   1,495   1,324
  Northern Border Pipeline              2,443   2,405   1,770

<FN>
(a) Billion British thermal units per day.  Amounts reflect
    100% of each entity's throughput volumes.  Florida Gas and
    Northern Border Pipeline are unconsolidated equity affiliates.
</TABLE>

   Significant components of IBIT are as follows:

<TABLE>
<CAPTION>
(In millions)                         2000   1999   1998

<S>                                   <C>    <C>    <C>
Net revenues                          $650   $626   $640
Operating expenses                     280    264    276
Depreciation and amortization           67     66     70
Equity earnings                         63     38     32
Other, net                              25     46     25
  Income before interest and taxes    $391   $380   $351
</TABLE>

Net Revenues
   Revenues, net of cost of sales, of Transportation Services
increased $24 million (4%) during 2000 and declined $14 million
(2%) during 1999 as compared to 1998.  In 2000, Transportation
Services' interstate pipelines produced strong financial results.
The volumes transported by Transwestern increased 13 percent in
2000 as compared to 1999.  Northern's 2000 gross margin was
comparable to 1999 despite an 8 percent decline in volumes
transported.  Net revenues in 2000 were favorably impacted by
transportation revenues from Transwestern's Gallup, New Mexico
expansion and by sales from Northern's gas storage inventory.  The
decrease in net revenue in 1999 compared to 1998 was primarily
due to the expiration, in October 1998, of certain transition
cost recovery surcharges, partially offset by a Northern sale of
gas storage inventory in 1999.

Operating Expenses
   Operating expenses, including depreciation and amortization,
of Transportation Services increased $17 million (5%) during 2000
primarily as a result of higher overhead costs related to
information technology and employee benefits.  Operating expenses
decreased $16 million (5%) during 1999 primarily as a result of
the expiration of certain transition cost recovery surcharges
which had been recovered through revenues.

Equity Earnings
   Equity in earnings of unconsolidated equity affiliates
increased $25 million and $6 million in 2000 and 1999,
respectively.  The increase in equity earnings in 2000 as
compared to 1999 primarily relates to Enron's investment in
Florida Gas.  The increase in earnings in 1999 as compared to
1998 was primarily a result of higher earnings from Northern
Border Pipeline and EOTT.

Other, Net
   Other, net decreased $21 million in 2000 as compared to
1999 after increasing $21 million in 1999 as compared to 1998.
Included in 2000 were gains related to an energy commodity
contract and the sale of compressor-related equipment, while the
1999 amount included interest income earned in connection with
the financing of an acquisition by EOTT.  The 1998 amount
included gains from the sale of an interest in an equity
investment, substantially offset by charges related to litigation.

   Portland General.  Portland General realized IBIT as follows:

<TABLE>
<CAPTION>
(In millions)                           2000     1999     1998

<S>                                    <C>      <C>      <C>
Revenues                               $2,256   $1,379   $1,196
Purchased power and fuel                1,461      639      451
Operating expenses                        321      304      295
Depreciation and amortization             211      181      183
Other, net                                 78       50       19
  Income before interest and taxes     $  341   $  305   $  286
</TABLE>

   Revenues, net of purchased power and fuel costs, increased $55
million in 2000 as compared to 1999.  The increase is primarily
the result of a significant increase in the price of power sold
and an increase in wholesale sales, partially offset by higher
purchased power and fuel costs.  Operating expenses increased
primarily due to increased plant maintenance costs related to
periodic overhauls.  Depreciation and amortization increased in
2000 primarily as a result of increased regulatory amortization.
Other, net in 2000 included the impact of an Oregon Public
Utility Commission (OPUC) order allowing certain deregulation costs
to be deferred and recovered through rate cases, the settlement of
litigation related to the Trojan nuclear power generating facility
and gains on the sale of certain generation-related assets.

   Revenues, net of purchased power and fuel costs, decreased $5
million in 1999 as compared to 1998.  Revenues increased
primarily as a result of an increase in the number of customers
served by Portland General.  Higher purchased power and fuel
costs, which increased 42 percent in 1999, offset the increase in
revenues.  Other income, net increased $31 million in 1999 as
compared to 1998 primarily as a result of a gain recognized on
the sale of certain assets.

   In 1999, Enron entered into an agreement to sell Portland
General Electric Company to Sierra Pacific Resources.  See Note 2
to the Consolidated Financial Statements.

   Statistics for Portland General are as follows:

<TABLE>
<CAPTION>
                                               2000      1999      1998

<S>                                           <C>       <C>       <C>
Electricity sales (thousand MWh)(a)
  Residential                                  7,433     7,404     7,101
  Commercial                                   7,527     7,392     6,781
  Industrial                                   4,912     4,463     3,562
     Total retail                             19,872    19,259    17,444
  Wholesale                                   18,548    12,612    10,869
     Total electricity sales                  38,420    31,871    28,313

Resource mix
  Coal                                            11%       15%       16%
  Combustion turbine                              12         8        12
  Hydro                                            6         9         9
     Total generation                             29        32        37
  Firm purchases                                  63        57        56
  Secondary purchases                              8        11         7
     Total resources                             100%      100%      100%

Average variable power cost (Mills/KWh)(b)
  Generation                                    14.5      11.3       8.6
  Firm purchases                                34.9      23.2      17.3
  Secondary purchases                          123.6      19.7      23.6
     Total average variable power cost          37.2      20.0      15.6

Retail customers (end of period, thousands)      725       719       704

<FN>
(a) Thousand megawatt-hours.
(b) Mills (1/10 cent) per kilowatt-hour.
</TABLE>

Outlook
   Enron Transportation Services is expected to provide stable
earnings and cash flows during 2001.  The four major natural gas
pipelines have strong competitive positions in their respective
markets as a result of efficient operating practices, competitive
rates and favorable market conditions.  Enron Transportation
Services expects to continue to pursue demand-driven expansion
opportunities.  Florida Gas expects to complete an expansion that
will increase throughput by 198 million cubic feet per day (MMcf/d)
by mid-2001.  Florida Gas has received preliminary approval from the
Federal Energy Regulatory Commission for an expansion of 428 MMcf/d,
expected to be completed by early 2003, and is also pursuing an
expansion of 150 MMcf/d that is expected to be completed in mid-2003.
Transwestern completed an expansion of 140 MMcf/d in May 2000 and
is pursuing an expansion of 50 MMcf/d that is expected to be
completed in 2001 and an additional expansion of up to 150 MMcf/d
that is expected to be completed in 2002.  Northern Border
Partners is evaluating the development of a 325 mile pipeline
with a range of capacity from 375 MMcf/d to 500 MMcf/d to connect
natural gas production in Wyoming to the Northern Border Pipeline
in Montana.

   In 2001, Portland General anticipates purchased power and
fuel costs to remain at historically high levels.  Portland
General has submitted a request with the OPUC to recover the
anticipated cost increase through a rate adjustment.

Wholesale Services
   Enron builds its wholesale businesses through the creation of
networks involving selective asset ownership, contractual access
to third-party assets and market-making activities.  Each market
in which Wholesale Services operates utilizes these components in
a slightly different manner and is at a different stage of
development.  This network strategy has enabled Wholesale
Services to establish a leading position in its markets.
Wholesale Services' activities are categorized into two business
lines:  (a) Commodity Sales and Services and (b) Assets and
Investments.  Activities may be integrated into a bundled product
offering for Enron's customers.

   Wholesale Services manages its portfolio of contracts and
assets in order to maximize value, minimize the associated risks
and provide overall liquidity.  In doing so, Wholesale Services
uses portfolio and risk management disciplines, including
offsetting or hedging transactions, to manage exposures to market
price movements (commodities, interest rates, foreign currencies
and equities).  Additionally, Wholesale Services manages its
liquidity and exposure to third-party credit risk through
monetization of its contract portfolio or third-party insurance
contracts.  Wholesale Services also sells interests in certain
investments and other assets to improve liquidity and overall
return, the timing of which is dependent on market conditions and
management's expectations of the investment's value.

   The following table reflects IBIT for each business line:

<TABLE>
<CAPTION>
(In millions)                      2000     1999     1998

<S>                               <C>      <C>      <C>
Commodity sales and services      $1,630   $  628   $ 411
Assets and investments               889      850     709
Unallocated expenses               (259)     (161)   (152)
  Income before interest,
   minority interests and taxes   $2,260   $1,317   $ 968
</TABLE>

   The following discussion analyzes the contributions to IBIT
for each business line.

   Commodity Sales and Services.  Wholesale Services provides
reliable commodity delivery and predictable pricing to its
customers through forwards and other contracts.  This market-
making activity includes the purchase, sale, marketing and
delivery of natural gas, electricity, liquids and other
commodities, as well as the management of Wholesale Services' own
portfolio of contracts.  Contracts associated with this activity
are accounted for using the mark-to-market method of accounting.
See Note 1 to the Consolidated Financial Statements.  Wholesale
Services' market-making activity is facilitated through a network
of capabilities including selective asset ownership.  Accordingly,
certain assets involved in the delivery of these services are
included in this business (such as intrastate natural gas pipelines,
gas storage facilities and certain electric generation assets).

   Wholesale Services markets, transports and provides energy
commodities as reflected in the following table (including
intercompany amounts):

<TABLE>
<CAPTION>
                                              2000     1999       1998

<S>                                         <C>        <C>       <C>
Physical volumes (BBtue/d)(a)(b)
Gas:
  United States                              17,674     8,982     7,418
  Canada                                      6,359     4,398     3,486
  Europe and Other                            3,637     1,572     1,251
                                             27,670    14,952    12,155
Transportation volumes                          649       575       559
     Total gas volumes                       28,319    15,527    12,714
Crude oil and Liquids                         6,088     6,160     3,570
Electricity(c)                               17,308    10,742    11,024
     Total physical volumes (BBtue/d)        51,715    32,429    27,308
Electricity volumes (thousand MWh)
  United States                             578,787   380,518   401,843
  Europe and Other                           54,670    11,576       529
     Total                                  633,457   392,094   402,372

Financial settlements (notional, BBtue/d)   196,148    99,337    75,266

<FN>
(a)  Billion British thermal units equivalent per day.
(b)  Includes third-party transactions by Enron Energy Services.
(c)  Represents electricity volumes, converted to BBtue/d.
</TABLE>

   Earnings from commodity sales and services increased $1.0
billion (160%) in 2000 as compared to 1999.  Increased profits
from North American gas and power marketing operations, European
power marketing operations as well as the value of new
businesses, such as pulp and paper, contributed to the earnings
growth of Enron's commodity sales and services business.
Continued market leadership in terms of volumes transacted,
significant increases in natural gas prices and price volatility
in both the gas and power markets were the key contributors to
increased profits in the gas and power intermediation businesses.
In late 1999, Wholesale Services launched an Internet-based
Ecommerce system, EnronOnline, which allows wholesale customers
to view Enron's real time pricing and to complete commodity
transactions with Enron as principal, with no direct interaction.
In its first full year of operation, EnronOnline positively
impacted wholesale volumes, which increased 59 percent over 1999
levels.

   Earnings from commodity sales and services increased $217
million (53%) in 1999 as compared to 1998, reflecting strong
results from the intermediation businesses in both North America
and Europe, which include delivery of energy commodities and
associated risk management products.  Wholesale Services also
successfully managed its overall portfolio of contracts,
particularly in minimizing credit exposures utilizing third-party
contracts.  New product offerings in coal and pulp and paper
markets also added favorably to the results.

   Assets and Investments.  Enron's Wholesale businesses make
investments in various energy and certain related assets as a
part of its network strategy.  Wholesale Services either
purchases the asset from a third party or develops and constructs
the asset.  In most cases, Wholesale Services operates and
manages such assets.  Earnings from these investments principally
result from operations of the assets or sales of ownership
interests.

   Additionally, Wholesale Services invests in debt and equity
securities of energy and technology-related businesses, which may
also utilize Wholesale Services' products and services.  With
these merchant investments, Enron's influence is much more
limited relative to assets Enron develops or constructs.
Earnings from these activities, which are accounted for on a
fair value basis and are included in revenues, result from
changes in the market value of the securities.  Wholesale Services
uses risk management disciplines, including hedging transactions,
to manage the impact of market price movements on its merchant
investments.  See Note 4 to the Consolidated Financial Statements
for a summary of these investments.

   Earnings from assets and investments increased $39 million
(5%) in 2000 as compared to 1999 as a result of an increase in
the value of Wholesale Services' merchant investments, partially
offset by lower gains from sales of energy assets.  Earnings from
asset operations were comparable to 1999 levels.  Earnings from
merchant investments were positively impacted by power-related
and energy investments, partially offset by the decline in value
of technology-related and certain energy-intensive industry
investments.  Gains on sales of energy assets in 2000 included
the monetization of certain European energy operations.

   Earnings from assets and investments increased $141 million
(20%) in 1999 as compared to 1998.  During 1999, earnings from
Wholesale Services' energy-related assets increased, reflecting
the operation of the Dabhol Power Plant in India, ownership in
Elektro Eletricidade e Servicos S.A. (Elektro), a Brazilian
electric utility, and assets in various other developing markets.
Wholesale Services' merchant investments increased in value
during the year due to the expansion into certain technology-
related investments, partially offset by a decline in the value
of certain energy investments.  In addition, Wholesale Services'
1999 earnings increased due to development and construction
activities, while gains on sales of energy assets declined.

   Unallocated Expenses.  Net unallocated expenses such as
systems expenses and performance-related costs increased in 2000
due to growth of Wholesale Services' existing businesses and
continued expansion into new markets.

Outlook
   In 2000, Wholesale Services reinforced its leading positions
in the natural gas and power markets in both North America and
Europe.  In the coming year, Wholesale Services plans to continue
to expand and refine its existing energy networks and to extend
its proven business model to new markets and industries.

   In 2001, Wholesale Services plans to continue to fine-tune its
already successful existing energy networks.  In North America,
Enron expects to complete the sale of five of its peaking power
plants located in the Midwest and its intrastate natural gas
pipeline.  In each case, market conditions, such as increased
liquidity, have diminished the need to own physical assets.  For
energy networks in other geographical areas where liquidity may
be an issue, Enron will evaluate whether its existing network
will benefit from additional physical assets.  The existing networks
in North America and Europe should continue to provide opportunities
for sustained volume growth and increased profits.

   The combination of knowledge gained in building networks in
key energy markets and the application of new technology, such as
EnronOnline, is expected to provide the basis to extend Wholesale
Services' business model to new markets and industries.  In key
international markets, where deregulation is underway, Enron
plans to build energy networks by using the optimum combination
of acquiring or constructing physical assets and securing
contractual access to third party assets.  Enron also plans to
replicate its business model to new industrial markets such as
metals, pulp, paper and lumber, coal and steel.  Enron expects to
use its Ecommerce platform, EnronOnline, to accelerate the
penetration into these industries.

   Earnings from Wholesale Services are dependent on the
origination and completion of transactions, some of which are
individually significant and which are impacted by market
conditions, the regulatory environment and customer
relationships.  Wholesale Services' transactions have
historically been based on a diverse product portfolio, providing
a solid base of earnings.  Enron's strengths, including its
ability to identify and respond to customer needs, access to
extensive physical assets and its integrated product offerings,
are important drivers of the expected continued earnings growth.
In addition, significant earnings are expected from Wholesale
Services' commodity portfolio and investments, which are subject
to market fluctuations.  External factors, such as the amount of
volatility in market prices, impact the earnings opportunity
associated with Wholesale Services' business.  Risk related to
these activities is managed using naturally offsetting
transactions and hedge transactions.  The effectiveness of
Enron's risk management activities can have a material impact on
future earnings.  See "Financial Risk Management" for a
discussion of market risk related to Wholesale Services.

Retail Energy Services
   Energy Services sells or manages the delivery of natural gas,
electricity, liquids and other commodities to industrial and
commercial customers located in North America and Europe.  Energy
Services also provides outsourcing solutions to customers for
full energy management.  This integrated product includes the
management of commodity delivery, energy information and energy
assets, and price risk management activities.  The commodity portion
of the contracts associated with this business are accounted for
using the mark-to-market method of accounting.  See Note 1 to
the Consolidated Financial Statements.

<TABLE>
<CAPTION>
(In millions)                              2000     1999     1998

<S>                                       <C>      <C>      <C>
Revenues                                  $4,615   $1,807   $1,072
Cost of sales                              4,028    1,551      955
Operating expenses                           449      308      210
Depreciation and amortization                 38       29       31
Equity losses                                (60)       -       (2)
Other, net                                    63       13        7
  IBIT before items impacting
   comparability                             103      (68)    (119)
Items impacting comparability:
   Gain  on  The New Power Company
    stock issuance                           121        -         -
  Retail Energy Services charges             (59)       -         -
Income (loss) before interest, minority
 interests and taxes                      $  165   $  (68)   $ (119)
</TABLE>

Operating Results
   Revenues and gross margin increased $2,808 million and $331
million, respectively, in 2000 compared to 1999, primarily
resulting from execution of commitments on its existing customer
base, long-term energy contracts originated in 2000 and the
increase in the value of Energy Services' contract portfolio.
Operating expenses increased as a result of costs incurred in
building the capabilities to deliver services on existing
customer contracts and in building Energy Services' outsourcing
business in Europe.  Other, net in 2000 consisted primarily of
gains associated with the securitization of non-merchant equity
instruments.  Equity losses reflect Energy Services' portion of
losses of The New Power Company.

   Items impacting comparability in 2000 included a pre-tax gain
of $121 million related to the issuance of common stock by The
New Power Company and a charge of $59 million related to the
write-off of certain information technology and other costs.
The New Power Company, which is approximately 45 percent owned
by Enron, was formed to provide electricity and natural gas to
residential and small commercial customers in deregulated
energy markets in the United States.

Outlook
   During 2001, Energy Services anticipates continued growth in
the demand for retail energy outsourcing solutions.  Energy
Services will deliver these services to its existing customers,
while continuing to expand its commercial and industrial customer
base for total energy outsourcing.  Energy Services also plans to
continue integrating its service delivery capabilities,
extend its business model to related markets and offer new
products.

Broadband Services
   In implementing Enron's network strategy, Broadband Services
is constructing the Enron Intelligent Network, a nationwide
fiber optic network that consists of both fiber deployed by Enron
and acquired capacity on non-Enron networks and is managed by
Enron's Broadband Operating System software.  Enron is extending
its market-making and risk management skills from its energy
business to develop the bandwidth intermediation business to help
customers manage unexpected fluctuation in the price, supply and
demand of bandwidth.  Enron's bandwidth-on-demand platform allows
delivery of high-bandwidth media-rich content such as video
streaming, high capacity data transport and video conferencing.
Broadband Services also makes investments in companies with
related technologies and with the potential for capital
appreciation.  Earnings from these merchant investments, which
are accounted for on a fair value basis and are included in
revenues, result from changes in the market value of the
securities.  Broadband Services uses risk management disciplines,
including hedging transactions, to manage the impact of market
price movements on its merchant investments.  Broadband Services
also sells interests in certain investments and other assets to
improve liquidity and overall return, the timing of which is
dependent on market conditions and management's expectations of
the investment's value.

   The components of Broadband Services' businesses include the
development and construction of the Enron Intelligent Network,
sales of excess fiber and software, bandwidth intermediation
and the delivery of content.  Significant components of Broadband
Services' results are as follows:

<TABLE>
<CAPTION>
(In millions)                            2000

<S>                                      <C>
Gross margin                             $318
Operating expenses                        305
Depreciation and amortization              77
Other, net                                  4
   Loss before interest, minority
    interests and taxes                  $(60)
</TABLE>

   Broadband Services recognized a loss before interest, minority
interests and taxes of $60 million in 2000.  Gross margin
included earnings from sales of excess fiber capacity, a
significant increase in the market value of Broadband Services'
merchant investments and the monetization of a portion of Enron's
broadband content delivery platform.  Expenses incurred during
the period include expenses related to building the business and
depreciation and amortization.

Outlook
   Broadband Services is extending Enron's proven business model
to the communications industry.  In 2001, Enron expects to
further develop the Enron Intelligent Network, a global broadband
network with broad connectivity potential to both buyers and
sellers of bandwidth through Enron's pooling points.  In
addition, Enron expects to further deploy its proprietary
Broadband Operating System across the Enron Intelligent Network,
enabling Enron to manage bandwidth capacity independent of owning
the underlying fiber.  Broadband Services expects its
intermediation transaction level to increase significantly in
2001 as more market participants connect to the pooling points
and transact with Enron to manage their bandwidth needs.  The
availability of Enron's bandwidth intermediation products and
prices on EnronOnline are expected to favorably impact the volume
of transactions.  In 2001, Broadband Services expects to continue
to expand the commercial roll-out of its content service
offerings including video-on-demand.  Enron expects the volume of
content delivered over its network to increase as more content
delivery contracts are signed and as more distribution partner
locations are connected.

Corporate and Other
   Significant components of Corporate and Other's IBIT are as
follows:

<TABLE>
<CAPTION>
(In millions)                                    2000    1999    1998

<S>                                             <C>      <C>     <C>
IBIT before items impacting comparability       $(289)   $(17)   $  7

Items impacting comparability:
  Charge to reflect impairment by Azurix         (326)      -       -
  Gains on exchange and sales of Enron Oil
   & Gas Company (EOG) stock                        -     454      22
  Charge to reflect impairment of MTBE assets
   and losses on contracted MTBE production         -    (441)    (61)
Loss before interest, minority interests
 and taxes                                      $(615)   $ (4)   $(32)
</TABLE>

   Results for Corporate and Other in 2000 reflect operating
losses from Enron's investment in Azurix (excluding the
impairments discussed below) and increased information technology,
employee compensation and corporate-wide expenses.

   Results for Corporate and Other in 1999 were impacted by
higher corporate expenses, partially offset by increased earnings
from EREC resulting from increased sales volumes from its German
manufacturing subsidiary and from the completion and sale of
certain domestic wind projects.  Enron also recognized higher
earnings related to Azurix.  Results in 1998 were favorably
impacted by increases in the market value of certain corporate-
managed financial instruments, partially offset by higher
corporate expenses.

   Items impacting comparability in 2000 included a $326 million
charge reflecting Enron's portion of impairments recorded by
Azurix related to assets in Argentina.  Items impacting comparability
in 1999 included a pre-tax gain of $454 million on the exchange and
sale of Enron's interest in EOG (see Note 2 to the Consolidated
Financial Statements) and a $441 million pre-tax charge for the
impairment of its MTBE assets (see Note 17 to the Consolidated
Financial Statements).

   During 1998, Enron recognized a pre-tax gain of $22 million on
the delivery of 10.5 million shares of EOG stock held by Enron as
repayment of mandatorily exchangeable debt.  Enron also recorded
a $61 million charge to reflect losses on contracted MTBE
production.

Interest and Related Charges, Net
   Interest and related charges, net of interest capitalized
which totaled $38 million, $54 million and $66 million for 2000,
1999 and 1998, respectively, increased to $838 million in 2000
from $656 million in 1999 and $550 million in 1998.  The increase
in 2000 as compared to 1999 was primarily a result of increased
long-term debt levels, increased average short-term borrowings,
short-term debt assumed as a result of the acquisition of MG plc
and higher interest rates in the U.S.  The increase was partially
offset by the replacement of debt related to a Brazilian subsidiary
with lower interest rate debt.

   The increase in 1999 as compared to 1998 was primarily due to
debt issuances and debt related to a Brazilian subsidiary, partially
offset by a decrease in debt related to EOG following the sale and
exchange of Enron's interests in August 1999.  See Note 2 to the
Consolidated Financial Statements.

Minority Interests
   Minority interests include the following:

<TABLE>
<CAPTION>
(In millions)                            2000   1999    1998

<S>                                      <C>    <C>     <C>
Elektro(a)                               $ 33   $ 39    $  -
Majority-owned limited liability
 company and limited partnerships         105     71       -
Enron Oil & Gas Company                     -      2      24
Other                                      16     23      53
   Total                                 $154   $135    $ 77

<FN>
(a) Relates to the respective parents of Elektro, which had
    minority shareholders in 2000 and 1999.  See Note 8 to
    the Consolidated Financial Statements.
</TABLE>

   Minority interests include Elektro beginning January 1, 1999,
a majority-owned limited liability company and majority-owned
limited partnerships since their formation during 1998 through
2000 and EOG until the exchange and sale of Enron's interests
in August 1999 (see Note 2 to the Consolidated Financial Statements).

Income Tax Expense
   Income tax expense increased in 2000 as compared to 1999
primarily as a result of increased earnings, decreased equity
earnings and decreased tax benefits related to the foreign tax
rate differential, partially offset by an increase in the
differences between the book and tax basis of certain assets and
stock sales.

   Income tax expense decreased in 1999 compared to 1998
primarily as a result of increased equity earnings, tax benefits
related to the foreign tax rate differential and the audit
settlement related to Monthly Income Preferred Shares, partially
offset by increased earnings.

Cumulative Effect of Accounting Changes
   In 1999, Enron recorded an after-tax charge of $131 million to
reflect the initial adoption (as of January 1, 1999) of two new
accounting pronouncements, the AICPA Statement of Position 98-5
(SOP 98-5), "Reporting on the Costs of Start-Up Activities," and
the Emerging Issues Task Force Issue No. 98-10, "Accounting for
Contracts Involved in Energy Trading and Risk Management
Activities."  The 1999 charge was primarily related to the
adoption of SOP 98-5.

NEW ACCOUNTING PRONOUNCEMENTS

   In 1998, the Financial Accounting Standards Board (FASB)
issued Statement of Financial Accounting Standards (SFAS) No.
133, "Accounting for Derivative Instruments and Hedging
Activities," which was subsequently amended by SFAS No. 137 and
SFAS No. 138.  SFAS No. 133 must be applied to all
derivative instruments and certain derivative instruments
embedded in hybrid instruments and requires that such instruments
be recorded in the balance sheet either as an asset or liability
measured at its fair value through earnings, with special
accounting allowed for certain qualifying hedges.  Enron will
adopt SFAS No. 133 as of January 1, 2001.  Due to
the adoption of SFAS No. 133, Enron will recognize
an after-tax non-cash loss of approximately $5 million in
earnings and an after-tax non-cash gain in "Other Comprehensive
Income," a component of shareholders' equity, of approximately
$22 million from the cumulative effect of a change in accounting
principle.  Enron will also reclassify $532 million from "Long-
Term Debt" to "Other Liabilities" due to the adoption.

   The total impact of Enron's adoption of SFAS No. 133
on earnings and on "Other Comprehensive Income" is
dependent upon certain pending interpretations, which are
currently under consideration, including those related to
"normal purchases and normal sales" and inflation escalators
included in certain contract payment provisions.  The
interpretations of these issues, and others, are currently under
consideration by the FASB.  While the ultimate conclusions
reached on interpretations being considered by the FASB could
impact the effects of Enron's adoption of SFAS No. 133,
Enron does not believe that such conclusions would have a material
effect on its current estimate of the impact of adoption.

FINANCIAL CONDITION

Cash Flows

<TABLE>
<CAPTION>
(In millions)                   2000      1999      1998

<S>                           <C>       <C>       <C>
Cash provided by (used in):
   Operating activities       $ 4,779   $ 1,228   $ 1,640
   Investing activities        (4,264)   (3,507)   (3,965)
   Financing activities           571     2,456     2,266
</TABLE>

   Net cash provided by operating activities increased $3,551
million in 2000, primarily reflecting decreases in working
capital, positive operating results and a receipt of cash
associated with the assumption of a contractual obligation.
Net cash provided by operating activities decreased $412
million in 1999, primarily reflecting increases in working
capital and net assets from price risk management activities,
partially offset by increased earnings and higher proceeds from
sales of merchant assets and investments.  The 1998 amount
reflects positive operating cash flow from Enron's major
business segments, proceeds from sales of interests in energy-
related merchant assets and cash from timing and other changes
related to Enron's commodity portfolio, partially offset by new
investments in merchant assets and investments.

   Net cash used in investing activities primarily reflects
capital expenditures and equity investments, which total $3,314
million in 2000, $3,085 million in 1999 and $3,564 million in
1998, and cash used for business acquisitions.  See "Capital
Expenditures and Equity Investments" below and see Note 2 to
the Consolidated Financial Statements for cash used for business
acquisitions.  Partially offsetting these uses of cash were proceeds
from sales of non-merchant assets, including certain equity instruments
by Energy Services and an international power project, which totaled
$494 million in 2000.  Proceeds from non-merchant asset sales were
$294 million in 1999 and $239 million in 1998.

   Cash provided by financing activities in 2000 included
proceeds from the issuance of subsidiary equity and the issuance
of common stock related to employee benefit plans, partially
offset by payments of dividends.  Cash provided by financing
activities in 1999 included proceeds from the net issuance of
short- and long-term debt, the issuance of common stock and
the issuance of subsidiary equity, partially offset by payments
of dividends.  Cash provided by financing activities in 1998
included proceeds from the net issuance of short- and long-term
debt, the issuance of common stock and the sale of a minority
interest in a subsidiary, partially offset by payments of dividends.

Capital Expenditures and Equity Investments
   Capital expenditures by operating segment are as follows:

<TABLE>
<CAPTION>
                                   2001
(In millions)                    Estimate   2000     1999     1998

<S>                               <C>      <C>      <C>      <C>
Transportation and Distribution   $  140   $  270   $  316   $  310
Wholesale Services                   570    1,280    1,216      706
Retail Energy Services                50       70       64       75
Broadband Services                   700      436        -        -
Exploration and Production             -        -      226      690
Corporate and Other                   40      325      541      124
  Total                           $1,500   $2,381   $2,363   $1,905
</TABLE>

   Capital expenditures increased $18 million in 2000 and
$458 million in 1999 as compared to the previous year.
Capital expenditures in 2000 primarily relate to construction of
power plants to extend Wholesale Services' network and fiber
optic network infrastructure for Broadband Services.  During
1999, Wholesale Services expenditures increased due primarily to
construction of domestic and international power plants.  The
1999 increase in Corporate and Other reflects the purchase of
certain previously leased MTBE-related assets.

   Cash used for investments in equity affiliates by the
operating segments is as follows:

<TABLE>
<CAPTION>
(In millions)                             2000   1999    1998

<S>                                       <C>    <C>    <C>
Transportation and Distribution           $  1   $  -   $   27
Wholesale Services                         911    712      703
Corporate and Other                         21     10      929
  Total                                   $933   $722   $1,659
</TABLE>

   Equity investments in 2000 relate primarily to capital
invested for the ongoing construction, by a joint venture, of a
power plant in India as well as other international investments.
Equity investments in 1999 relate primarily to an investment in a
joint venture that holds gas distribution and related
businesses in South Korea and the power plant project in India.

   The level of spending for capital expenditures and equity
investments will vary depending upon conditions in the energy and
broadband markets, related economic conditions and identified
opportunities.  Management expects that the capital spending
program will be funded by a combination of internally generated
funds, proceeds from dispositions of selected assets and short-
and long-term borrowings.

Working Capital
   At December 31, 2000, Enron had working capital of $2.0
billion.  If a working capital deficit should occur, Enron has
credit facilities in place to fund working capital requirements.
At December 31, 2000, those credit lines provided for up to $4.2
billion of committed and uncommitted credit, of which $290
million was outstanding.  Certain of the credit agreements
contain prefunding covenants.  However, such covenants are not
expected to restrict Enron's access to funds under these
agreements.  In addition, Enron sells commercial paper and has
agreements to sell trade accounts receivable, thus providing
financing to meet seasonal working capital needs.  Management
believes that the sources of funding described above are
sufficient to meet short- and long-term liquidity needs not met
by cash flows from operations.

CAPITALIZATION

   Total capitalization at December 31, 2000 was $25.0 billion.
Debt as a percentage of total capitalization increased to 40.9%
at December 31, 2000 as compared to 38.5% at December 31, 1999.
The increase in the ratio primarily reflects increased debt
levels and the impact on total equity of the decline in the value
of the British pound sterling.  This was partially offset by the
issuances, in 2000, of Enron common stock and the contribution of
common shares (see Note 16 to the Consolidated Financial
Statements).  The issuances of Enron common stock primarily related
to the acquisition of a minority shareholder's interest in Enron Energy
Services, LLC and the exercise of employee stock options.

   Enron is a party to certain financial contracts which contain
provisions for early settlement in the event of a significant
market price decline in which Enron's common stock falls below
certain levels (prices ranging from $28.20 to $55.00 per share)
or if the credit ratings for Enron's unsecured, senior long-term
debt obligations fall below investment grade.  The impact of this
early settlement could include the issuance of additional shares
of Enron common stock.

   Enron's senior unsecured long-term debt is currently rated
BBB+ by Standard & Poor's Corporation and Fitch IBCA and Baa1 by Moody's
Investor Service.  Enron's continued investment grade status is
critical to the success of its wholesale businesses as well as
its ability to maintain adequate liquidity.  Enron's management
believes it will be able to maintain its credit rating.

ITEM 7A. FINANCIAL RISK MANAGEMENT

   Wholesale Services offers price risk management services
primarily related to commodities associated with the energy
sector (natural gas, electricity, crude oil and natural gas
liquids). Energy Services and Broadband Services also offer
price risk management services to their customers.  These
services are provided through a variety of financial instruments
including forward contracts, which may involve physical delivery,
swap agreements, which may require payments to (or receipt of
payments from) counterparties based on the differential between a
fixed and variable price for the commodity, options and other
contractual arrangements. Interest rate risks and foreign
currency risks associated with the fair value of Wholesale
Services' commodities portfolio are managed using a variety
of financial instruments, including financial futures, swaps
and options.

   On a much more limited basis, Enron's other businesses also
enter into financial instruments such as forwards, swaps and
other contracts primarily for the purpose of hedging the impact
of market fluctuations on assets, liabilities, production or
other contractual commitments.  Changes in the market value of
these hedge transactions are deferred until the gain or loss is
recognized on the hedged item.

   Enron manages market risk on a portfolio basis, subject to
parameters established by its Board of Directors. Market risks
are monitored by an independent risk control group operating
separately from the units that create or actively manage these
risk exposures to ensure compliance with Enron's stated risk
management policies.

Market Risk
   The use of financial instruments by Enron's businesses may
expose Enron to market and credit risks resulting from adverse
changes in commodity and equity prices, interest rates and
foreign exchange rates.  For Enron's businesses, the major market
risks are discussed below:

   Commodity Price Risk.  Commodity price risk is a consequence
of providing price risk management services to customers.  As
discussed above, Enron actively manages this risk on a portfolio
basis to ensure compliance with Enron's stated risk management
policies.

   Interest Rate Risk. Interest rate risk is also a consequence
of providing price risk management services to customers and
having variable rate debt obligations, as changing interest rates
impact the discounted value of future cash flows. Enron utilizes
forwards, futures, swaps and options to manage its interest rate
risk.

   Foreign Currency Exchange Rate Risk. Foreign currency exchange
rate risk is the result of Enron's international operations and
price risk management services provided to its worldwide customer
base.  The primary purpose of Enron's foreign currency hedging
activities is to protect against the volatility associated with
foreign currency purchase and sale transactions. Enron primarily
utilizes forward exchange contracts, futures and purchased
options to manage Enron's risk profile.

     Equity Risk. Equity risk arises from Enron's participation
in investments.  Enron generally manages this risk by hedging
specific investments using futures, forwards, swaps and options.

   Enron evaluates, measures and manages the market risk in its
investments on a daily basis utilizing value at risk and other
methodologies.  The quantification of market risk using value at
risk provides a consistent measure of risk across diverse markets
and products. The use of these methodologies requires a number of
key assumptions including the selection of a confidence level for
expected losses, the holding period for liquidation and the
treatment of risks outside the value at risk methodologies,
including liquidity risk and event risk.  Value at risk
represents an estimate of reasonably possible net losses in
earnings that would be recognized on its investments assuming
hypothetical movements in future market rates and no change in
positions.  Value at risk is not necessarily indicative of actual
results which may occur.

Value at Risk
     Enron has performed an entity-wide value at risk analysis of
virtually all of Enron's financial instruments, including price
risk management activities and merchant investments.  Value at
risk incorporates numerous variables that could impact the fair
value of Enron's investments, including commodity prices,
interest rates, foreign exchange rates, equity prices and
associated volatilities, as well as correlation within and across
these variables.  Enron estimates value at risk for commodity,
interest rate and foreign exchange exposures using a model based
on Monte Carlo simulation of delta/gamma positions which captures
a significant portion of the exposure related to option
positions.  The value at risk for equity exposure discussed above
is based on J.P. Morgan's RiskMetrics(TM) approach.  Both value at
risk methods utilize a one-day holding period and a 95%
confidence level.  Cross-commodity correlations are used as
appropriate.

   The use of value at risk models allows management to aggregate
risks across the company, compare risk on a consistent basis and
identify the drivers of risk.  Because of the inherent
limitations to value at risk, including the use of delta/gamma
approximations to value options, subjectivity in the choice of
liquidation period and reliance on historical data to calibrate
the models, Enron relies on value at risk as only one component
in its risk control process.  In addition to using value at risk
measures, Enron performs regular stress and scenario analyses to
estimate the economic impact of sudden market moves on the value
of its portfolios.  The results of the stress testing, along with
the professional judgment of experienced business and risk
managers, are used to supplement the value at risk methodology
and capture additional market-related risks, including
volatility, liquidity and event, concentration and correlation
risks.

   The following table illustrates the value at risk for each
component of market risk:

<TABLE>
<CAPTION>
                              December 31,      Year ended December 31, 2000
                                                            High            Low
(In millions)                 2000   1999   Average(a)   Valuation(a)   Valuation(a)

<S>                            <C>   <C>       <C>          <C>             <C>
Trading Market Risk:
  Commodity price(b)           $66   $21       $50           $81            $23
  Interest rate                  -     -         -             -              -
  Foreign currency
   exchange rate                 -     -         -             -              -
  Equity(c)                     59    26        45            59             36

Non-Trading Market Risk(d):
  Commodity price                2     1         2             5              2
  Interest rate                  -     2         1             2              -
  Foreign currency
   exchange rate                 8     4         8            10              4
  Equity                         7     3         6             7              5

<FN>
(a)  The average value presents a twelve month average of the
     month-end values.  The high and low valuations for each market
     risk component represent the highest and lowest month-end value
     during 2000.
(b)  In 2000, increased natural gas prices combined with
     increased price volatility in power and gas markets caused
     Enron's value at risk to increase significantly.
(c)  Enron's equity trading market risk primarily relates to
     merchant investments (see Note 4 to the Consolidated Financial
     Statements).  In 2000, the value at risk model utilized for
     equity trading market risk was refined to more closely correlate
     with the valuation methodologies used for merchant activities.
(d)  Includes only the risk related to the financial instruments
     that serve as hedges and does not include the related underlying
     hedged item.
</TABLE>

Accounting Policies
   Accounting policies for price risk management and hedging
activities are described in Note 1 to the Consolidated Financial
Statements.


                      INFORMATION REGARDING
                   FORWARD-LOOKING STATEMENTS

   This Report includes forward-looking statements within the
meaning of Section 27A of the Securities Act of 1933 and
Section 21E of the Securities Exchange Act of 1934.  All
statements other than statements of historical facts
contained in this document are forward-looking statements.
Forward-looking statements include, but are not limited to,
statements relating to expansion opportunities for the
Transportation Services, extension of Enron's business model to
new markets and industries, demand in the market for broadband
services and high bandwidth applications, transaction volumes in
the U.S. power market, commencement of commercial operations of
new power plants and pipeline projects, completion of the sale
of certain assets and growth in the demand for retail energy
outsourcing solutions.  When used in this document, the words
"anticipate," "believe," "estimate," "expects," "intend," "may,"
"project," "plan," "should" and similar expressions are intended
to be among the statements that identify forward-looking
statements.  Although Enron believes that its expectations
reflected in these forward-looking statements are based on
reasonable assumptions, such statements involve risks and
uncertainties and no assurance can be given that actual results
will be consistent with these forward-looking statements.
Important factors that could cause actual results to differ
materially from those in the forward-looking statements herein
include success in marketing natural gas and power to wholesale
customers; the ability of Enron to penetrate new retail natural
gas and electricity markets (including energy outsourcing
markets) in the United States and foreign jurisdictions;
development of Enron's broadband network and customer demand for
intermediation and content services; the timing, extent and
market effects of deregulation of energy markets in the United
States, including the current energy market conditions in
California, and in foreign jurisdictions; other regulatory
developments in the United States and in foreign countries,
including tax legislation and regulations; political developments
in foreign countries; the extent of efforts by governments to
privatize natural gas and electric utilities and other
industries; the timing and extent of changes in commodity prices
for crude oil, natural gas, electricity, foreign currency and
interest rates; the extent of success in acquiring oil and gas
properties and in discovering, developing, producing and
marketing reserves; the timing and success of Enron's efforts to
develop international power, pipeline and other infrastructure
projects; the effectiveness of Enron's risk management
activities; the ability of counterparties to financial risk
management instruments and other contracts with Enron to meet
their financial commitments to Enron; and Enron's ability to
access the capital markets and equity markets during the periods
covered by the forward-looking statements, which will depend on
general market conditions and Enron's ability to maintain the
credit ratings for its unsecured senior long-term debt obligations.

<PAGE>

Item 8.  FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA

     The information required hereunder is included in this
report as set forth in the "Index to Financial Statements"
on page F-1.


Item 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON
        ACCOUNTING AND FINANCIAL DISCLOSURE

        None.


                          PART III

Item 10.  DIRECTORS AND EXECUTIVE OFFICERS OF THE REGISTRANT

     The information required by Item 10 of Form 10-K
relating to directors who are nominees for election as
directors at Enron's Annual Meeting of Shareholders to be
held on May 1, 2001 is set forth under the caption entitled
"Election of Directors" in Enron's Proxy Statement, and is
incorporated herein by reference.

     The information required by Item 10 of Form 10-K with
respect to executive officers is set forth in Part I of this
Form 10-K under the heading "Current Executive Officers of
the Registrant".

     Section 16(a) of the Securities Exchange Act of 1934
requires Enron's executive officers and directors, and
persons who own more than 10% of a registered class of
Enron's equity securities, to file reports of ownership and
changes in ownership with the SEC and the New York Stock
Exchange.  Based solely on its review of the copies of such
reports received by it, or written representations from
certain reporting persons that no Forms 5 were required for
those persons, Enron believes that during 2000, its
executive officers, directors and greater than 10%
shareholders complied with all applicable filing
requirements, with the exception that:  three transactions,
all reflecting the deemed acquisition and disposition of
common stock upon the exercise of derivative phantom stock
units on January 24, 2000, for either cash or phantom units
in the Enron Deferral Plan, for each of John C. Baxter,
Richard B. Buy, Andrew S. Fastow, Mark A. Frevert and
Kenneth D. Rice were not timely reported; one exempt stock
option grant for J. Mark Metts and one exempt phantom stock
unit grant for John Wakeham were not timely reported; and
Lawrence Ruben did not timely file one report containing a
private transaction with family members.

     There are no family relationships among the officers
listed, and there are no arrangements or understandings
pursuant to which any of them were elected as officers.
Officers are appointed or elected annually by the Board of
Directors at its first meeting following the Annual Meeting
of Shareholders, each to hold office until the corresponding
meeting of the Board in the next year or until a successor
shall have been elected, appointed or shall have qualified.

Item 11.  EXECUTIVE COMPENSATION

     The information regarding executive compensation is set
forth in the Proxy Statement under the captions
"Compensation of Directors and Executive Officers --Director
Compensation; Executive Compensation; Stock Option Grants
During 2000; Aggregated Stock Option/SAR Exercises During
2000 and Stock Option/SAR Values as of December 31, 2000;
Retirement and Supplemental Benefit Plans; Severance Plans;
Employment Contracts; and Certain Transactions", and is
incorporated herein by reference.

Item 12.  SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS
          AND MANAGEMENT

 (a) Security ownership of certain beneficial owners

     The information regarding security ownership of certain beneficial
     owners is set forth in the Proxy Statement under the caption
     "Election of Directors - Security Ownership of Certain Beneficial
     Owners", and is incorporated herein by reference.

 (b) Security ownership of management

     The information regarding security ownership of management is set
     forth in the Proxy Statement under the caption "Election of Directors
     - Stock Ownership of Management and Board of Directors as of
     February 15, 2001", and is incorporated herein by reference.

 (c)  Changes in control

      None.

Item 13.  CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS

     The information regarding certain relationships and
related transactions is set forth in the Proxy Statement
under the caption "Certain Transactions" and "Compensation
Committee Interlocks and Insider Participation", and is
incorporated herein by reference.


                           PART IV

Item 14.  EXHIBITS, FINANCIAL STATEMENT SCHEDULES, AND
          REPORTS ON FORM 8-K

(a)(1) and (2) Financial Statements and Financial Statement
Schedules.  See "Index to Financial Statements" set forth on
page F-1.

(a)(3)   Exhibits:

*3.01  -  Amended and Restated Articles of Incorporation of
          Enron Oregon Corp. (Annex E to the Proxy
          Statement/Prospectus included in Enron's
          Registration Statement on Form S-4 - File No. 333-
          13791).

 *3.02  - Articles of Merger of Enron Oregon Corp., an Oregon
          corporation, and Enron Corp., a Delaware
          corporation (Exhibit 3.02 to Post-Effective
          Amendment No. 1 to Enron's Registration Statement
          on Form S-3 - File No. 33-60417).

 *3.03  - Articles of Merger of Enron Corp., an Oregon
          corporation, and Portland General Corporation, an
          Oregon corporation (Exhibit 3.03 to Post-Effective
          Amendment No. 1 to Enron's Registration Statement
          on Form S-3 - File No. 33-60417).

 *3.04  - Bylaws of Enron (Exhibit 3.04 to Post-Effective
          Amendment No. 1 to Enron's Registration Statement
          on Form S-3 - File No. 33-60417).

 *3.05  - Articles of Amendment of Enron:  Form of Series
          Designation for the Enron Convertible Preferred
          Stock (Annex F to the Proxy Statement/Prospectus
          included in Enron's Registration Statement on Form
          S-4 - File No. 333-13791).

 *3.06  - Articles of Amendment of Enron:  Form of Series
          Designation for the Enron 9.142% Preferred Stock
          (Annex G to the Proxy Statement/Prospectus included
          in Enron's Registration Statement on Form S-4 -
          File No. 333-13791).

 *3.07  - Articles of Amendment of Enron:  Statement of
          Resolutions Establishing Series A Junior Voting
          Convertible Preferred Stock (Exhibit 3.07 to
          Enron's Registration Statement on Form S-3 - File
          No. 333-44133).

 *3.08  - Articles of Amendment of Enron:  Statement of
          Resolutions Establishing A Series of Preferred
          Stock of Enron Corp. - Mandatorily Convertible
          Single Reset Preferred Stock, Series A (Exhibit
          4.01 to Enron's Form 8-K filed on January 26,
          1999).

 *3.09  - Articles of Amendment of Enron:  Statement of
          Resolutions Establishing A Series of Preferred
          Stock of Enron Corp. - Mandatorily Convertible
          Single Reset Preferred Stock, Series B (Exhibit
          4.02 to Enron's Form 8-K filed on January 26,
          1999).

 *3.10  - Articles of Amendment of Enron amending Article IV
          of the Articles of Incorporation (Exhibit 3.10 to
          Post-Effective Amendment No. 1 to Enron's
          Registration Statement on Form S-3 - File No. 333-
          70465).

 *3.11  - Articles of Amendment of Enron:  Statement of
          Resolutions Establishing A Series of Preferred
          Stock of Enron Corp. - Mandatorily Convertible
          Junior Preferred Stock, Series B (Exhibit 3.11 to
          Post-Effective Amendment No. 1 to Enron's
          Registration Statement on Form S-3 - File No. 333-
          70465).

 *4.01  - Indenture dated as of November 1, 1985, between
          Enron and Harris Trust and Savings Bank (now The
          Bank of New York), as supplemented and amended by
          the First Supplemental Indenture dated as of
          December 1, 1995 (Form T-3 Application for
          Qualification of Indentures under the Trust
          Indenture Act of 1939, File No. 22-14390, filed
          October 24, 1985; Exhibit 4(b) to Form S-3
          Registration Statement No. 33-64057 filed on
          November 8, 1995).  There have not been filed as
          exhibits to this Form 10-K other debt instruments
          defining the rights of holders of long-term debt of
          Enron, none of which relates to authorized
          indebtedness that exceeds 10% of the consolidated
          assets of Enron and its subsidiaries.  Enron hereby
          agrees to furnish a copy of any such instrument to
          the Commission upon request.

 *4.02 -  Supplemental Indenture, dated as of May 8, 1997,
          by and among Enron Corp., Enron Oregon
          Corp. and Harris Trust and Savings Bank (now The
          Bank of New York), as Trustee (Exhibit 4.02 to Post-
          Effective Amendment No. 1 to Enron's Registration
          Statement on Form S-3, File No. 33-60417).

 *4.03  - Third Supplemental Indenture, dated as of September
          1, 1997, between Enron Corp. and Harris Trust and
          Savings Bank (now The Bank of New York), as Trustee
          (Exhibit 4.03 to Enron Registration Statement on
          Form S-3, File No. 333-35549).

 *4.04  - Fourth Supplemental Indenture, dated as of August
          17, 1999, between Enron Corp. and Harris Trust and
          Savings Bank (now The Bank of New York), as Trustee
          (Exhibit 4.05 to Enron Registration Statement on
          Form S-3 - File No. 333-83549).

Executive Compensation Plans and Arrangements Filed as
Exhibits Pursuant to Item 14(c) of Form 10-K:  Exhibits 10.01
through 10.53

*10.01  - Enron Executive Supplemental Survivor Benefits
          Plan, effective January 1, 1987 (Exhibit 10.01 to
          Enron Form 10-K for 1992).

*10.02  - First Amendment to Enron Executive
          Supplemental Survivor Benefits Plan (Exhibit 10.02
          to Enron Form 10-K for 1999).

*10.03  - Enron Corp. 1988 Stock Plan (Exhibit 4.3 to Form S-
          8 Registration Statement No. 33-27893).

*10.04  - Second Amendment to Enron Corp. 1988 Stock Plan
          (Exhibit 10.04 to Enron Form 10-K for 1996).

*10.05  - Enron Corp. 1988 Deferral Plan (Exhibit 10.19 to
          Enron Form 10-K for 1987).

*10.06  - First Amendment to Enron Corp. 1988 Deferral Plan
          (Exhibit 10.06 to Enron Form 10-K for 1995).

*10.07  - Second Amendment to Enron Corp. 1988 Deferral Plan
          (Exhibit 10.07 to Enron Form 10-K for 1995).

*10.08  - Third Amendment to Enron Corp. 1988 Deferral Plan
          (Exhibit 10.09 to Enron Form 10-K for 1996).

*10.09  - Fourth Amendment to Enron Corp. 1988 Deferral Plan
          (Exhibit 10.10 to Enron Form 10-K for 1996).

*10.10  - Fifth Amendment to Enron Corp. 1988 Deferral Plan
          (Exhibit 10.11 to Enron Form 10-K for 1996).

*10.11  - Sixth Amendment to Enron Corp. 1988 Deferral Plan
          (Exhibit 10.11 to Enron Form 10-K for 1999).

*10.12  - Enron Corp. 1991 Stock Plan (Exhibit 10.08 to Enron
          Form 10-K for 1991).

*10.13  - Amended and Restated Enron Corp. 1991 Stock Plan
          (Exhibit A to Enron Proxy Statement filed pursuant
          to Section 14(a) on March 24, 1997).

*10.14  - First Amendment to Enron Corp. Amended and Restated
          1991 Stock Plan (Exhibit 10.13 to Enron Form 10-K
          for 1997).

*10.15  - Second Amendment to Enron Corp. Amended and
          Restated 1991 Stock Plan (Exhibit 10.14 to Enron
          Form 10-K for 1997).

*10.16  - Enron Corp. 1991 Stock Plan (As Amended and
          Restated Effective May 4, 1999) (Exhibit B to Enron
          Proxy Statement filed pursuant to Section 14(a) on
          March 30, 1999).

*10.17  - First Amendment to Enron Corp. 1991 Stock Plan (As
          Amended and Restated Effective May 4, 1999)
          (Exhibit 10.17 to Enron Form 10-K for 1999).

*10.18  - Second Amendment to Enron Corp. 1991 Stock Plan (As
          Amended and Restated Effective May 4, 1999)
          (Exhibit 10.18 to Enron Form 10-K for 1999).

*10.19  - Third Amendment to Enron Corp. 1991 Stock Plan (As
          Amended and Restated Effective May 4, 1999)
          (Exhibit 10.19 to Enron Form 10-K for 1999).

*10.20  - Enron Corp. 1992 Deferral Plan (Exhibit 10.09 to
          Enron Form 10-K for 1991).

*10.21  - First Amendment to Enron Corp. 1992 Deferral Plan
          (Exhibit 10.10 to Enron Form 10-K for 1995).

*10.22  - Second Amendment to Enron Corp. 1992 Deferral Plan
          (Exhibit 10.11 to Enron Form 10-K for 1995).

*10.23  - Enron Corp. Directors' Deferred Income Plan
          (Exhibit 10.09 to Enron Form 10-K for 1992).

*10.24  - Split Dollar Life Insurance Agreement between Enron
          and the KLL and LPL Family Partnership, Ltd., dated
          April 22, 1994 (Exhibit 10.17 to Enron Form 10-K
          for 1994).

*10.25  - Employment Agreement between Enron Corp. and
          Kenneth L. Lay, executed December 18, 1996 (Exhibit
          10.25 to Enron Form 10-K for 1996).

*10.26  - First Amendment to Employment Agreement between
          Enron Corp. and Kenneth L. Lay, dated February 7,
          2000 (Exhibit 10.26 to Enron Form 10-K for 1999).

*10.27  - Consulting Services Agreement between Enron and
          John A. Urquhart dated August 1, 1991 (Exhibit
          10.23 to Enron Form 10-K for 1991).

*10.28  - First Amendment to Consulting Services Agreement
          between Enron and John A. Urquhart, dated August
          27, 1992 (Exhibit 10.25 to Enron Form 10-K for
          1992).

*10.29  - Second and Third Amendments to Consulting Services
          Agreement between Enron and John A. Urquhart, dated
          November 24, 1992 and February 26, 1993,
          respectively (Exhibit 10.26 to Enron Form 10-K for
          1992).

*10.30  - Fourth Amendment to Consulting Services Agreement
          between Enron and John A. Urquhart dated as of May
          9, 1994 (Exhibit 10.35 to Enron Form 10-K for
          1995).

*10.31 -  Fifth Amendment to Consulting Services Agreement
          between Enron and John A. Urquhart (Exhibit 10.36
          to Enron Form 10-K for 1995).

*10.32  - Sixth Amendment to Consulting Services Agreement
          between Enron and John A. Urquhart (Exhibit 10.37
          to Enron Form 10-K for 1995).

*10.33  - Seventh Amendment to Consulting Services Agreement
          between Enron and John A. Urquhart, dated October
          27, 1997 (Exhibit 10.27 to Enron Form 10-K for
          1997).

*10.34  - Eighth Amendment to Consulting Services Agreement
          between Enron and John A. Urquhart, dated May 27,
          1998 (Exhibit 10.28 to Enron Form 10-K for 1998).

*10.35  - Ninth Amendment to Consulting Services Agreement
          between Enron and John A. Urquhart, dated December
          31, 1998 (Exhibit 10.29 to Enron Form 10-K for
          1998).

*10.36  - Tenth Amendment to Consulting Services Agreement
          between John A. Urquhart and Enron Corp. dated
          January 1, 2000 (Exhibit 10.36 to Enron Form 10-K
          for 1999).

*10.37  - Enron Corp. Performance Unit Plan (Exhibit A to
          Enron Proxy Statement filed pursuant to Section
          14(a) on March 25, 1994).

*10.38  - Enron Corp. Annual Incentive Plan (Exhibit B to
          Enron Proxy Statement filed pursuant to Section
          14(a) on March 25, 1994).

*10.39  - Enron Corp. Annual Incentive Plan dated May 4, 1999
          (Exhibit A to Enron Proxy Statement filed pursuant
          to Section 14(a) on March 30, 1999).

*10.40  - Enron Corp. Performance Unit Plan (as amended and
          restated effective May 2, 1995) (Exhibit A to Enron
          Proxy Statement filed pursuant to Section 14(a) on
          March 27, 1995).

*10.41  - First Amendment to Enron Corp. Performance Unit
          Plan (Exhibit 10.46 to Enron Form 10-K for 1995).

*10.42  - Enron Corp. Restated 1994 Deferral Plan (Exhibit
          4.3 to Enron Form S-8 Registration Statement, File
          No. 333-48193).

*10.43  - Employment Agreement between Enron Capital Trade &
          Resources Corp. and Jeffrey K. Skilling, dated
          January 1, 1996 (Exhibit 10.63 to Enron Form 10-K
          for 1996).

*10.44  - First Amendment effective January 1, 1997, by and
          among Enron Corp., Enron Capital & Trade Resources
          Corp., and Jeffrey K. Skilling, amending Employment
          Agreement between Enron Capital & Trade Resources
          Corp. and Jeffrey K. Skilling dated January 1, 1996
          (Exhibit 10.64 to Enron Form 10-K for 1996).

*10.45  - Split Dollar Agreement between Enron and Jeffrey K.
          Skilling dated May 23, 1997 (Exhibit 10.41 to Enron
          Form 10-K for 1997).

*10.46  - Second Amendment effective October 13, 1997, to
          Employment Agreement between Enron Corp. and
          Jeffrey K. Skilling (Exhibit 10.42 to Enron Form
          10-K for 1997).

*10.47  - Loan Agreement effective October 13, 1997, between
          Enron Corp. and Jeffrey K. Skilling (Exhibit 10.43
          to Enron Form 10-K for 1997).

*10.48  - Third Amendment to Employment Agreement between
          Enron Corp. and Jeffrey K. Skilling, dated February
          7, 2000 (Exhibit 10.48 to Enron Form 10-K for
          1999).

*10.49  - Executive Employment Agreement between Enron
          Operations Corp. and Stanley C. Horton, dated as
          of October 1, 1999 (Exhibit 10.45 to Enron Form 10-
          K for 1997).

*10.50  - First Amendment to Executive Employment Agreement
          by and between Enron Operations Corp., Enron Corp.
          and Stanley C. Horton, dated December 27, 1999
          (Exhibit 10.56 to Enron Form 10-K for 1999).

 10.51  - Employment Agreement between Enron Corp. and Mark
          A. Frevert, effective March 1, 2000

*10.52  - Executive Employment Agreement between Enron Corp.
          and Kenneth D. Rice, effective June 1, 1998
          (Exhibit 10.43 to Enron Form 10-K for 1998).

 10.53  - First Amendment to Executive Employment Agreement
          between Enron Corp. and Kenneth D. Rice, dated
          February 14, 2000.

 12     - Statement re computation of ratios of earnings to
          fixed charges.

 21     - Subsidiaries of registrant.

 23.01  - Consent of Arthur Andersen LLP.

 23.02  - Consent of Arthur Andersen LLP.

 24     - Powers of Attorney for the directors signing
          this Form 10-K.

 99     - Financial Statements of Atlantic Water Trust.




 *    Asterisk indicates exhibits incorporated by reference.

(b)   Reports on Form 8-K

      Current Report on Form 8-K filed February 28, 2001.

<PAGE>
                 INDEX TO FINANCIAL STATEMENTS

                          ENRON CORP.

                                                        Page No.

Consolidated Financial Statements


  Report of Independent Public Accountants               F-2

  Consolidated Income Statement and Consolidated
  Statement of Comprehensive Income for the years
  ended December 31, 2000, 1999 and 1998                 F-3

  Consolidated Balance Sheet as of December 31, 2000
  and 1999                                               F-4

  Consolidated Statement of Cash Flows for the years
  ended December 31, 2000, 1999 and 1998                 F-6

  Consolidated Statement of Changes in Shareholders'
  Equity Accounts for the years ended December 31, 2000,
  1999 and 1998                                          F-7

  Notes to the Consolidated Financial Statements         F-8

Financial Statements Schedule

  Report of Independent Public Accountants on
  Financial Statement Schedule                           S-1

  Schedule II  -  Valuation and Qualifying Accounts      S-2


   Other  financial  statement schedules have  been  omitted
because  they  are inapplicable or the information  required
therein is included elsewhere in the financial statements or
notes thereto.




<PAGE>
REPORT OF INDEPENDENT PUBLIC ACCOUNTANTS

To the Shareholders and Board of Directors of Enron Corp.:

   We have audited the accompanying consolidated balance sheet of
Enron Corp. (an Oregon corporation) and subsidiaries as of
December 31, 2000 and 1999, and the related consolidated
statements of income, comprehensive income, cash flows and
changes in shareholders' equity for each of the three years in
the period ended December 31, 2000.  These financial statements
are the responsibility of Enron Corp.'s management.  Our
responsibility is to express an opinion on these financial
statements based on our audits.

   We conducted our audits in accordance with auditing standards
generally accepted in the United States.  Those standards require
that we plan and perform the audit to obtain reasonable assurance
about whether the financial statements are free of material
misstatement.  An audit includes examining, on a test basis,
evidence supporting the amounts and disclosures in the financial
statements.  An audit also includes assessing the accounting
principles used and significant estimates made by management, as
well as evaluating the overall financial statement presentation.
We believe that our audits provide a reasonable basis for our
opinion.

   In our opinion, the financial statements referred to above
present fairly, in all material respects, the financial position
of Enron Corp. and subsidiaries as of December 31, 2000 and 1999,
and the results of their operations, cash flows and changes in
shareholders' equity for each of the three years in the period
ended December 31, 2000, in conformity with accounting principles
generally accepted in the United States.

   As discussed in Note 18 to the consolidated financial
statements, Enron Corp. and subsidiaries changed its method of
accounting for costs of start-up activities and its method of
accounting for certain contracts involved in energy trading and
risk management activities in the first quarter of 1999.




                       Arthur Andersen LLP

Houston, Texas
February 23, 2001



<PAGE>
<TABLE>
                  ENRON CORP. AND SUBSIDIARIES
                  CONSOLIDATED INCOME STATEMENT

<CAPTION>
                                                         Year ended December 31,
(In millions, except per share amounts)                 2000       1999      1998

<S>                                                   <C>        <C>       <C>
Revenues
  Natural gas and other products                      $ 50,500   $19,536   $13,276
  Electricity                                           33,823    15,238    13,939
  Metals                                                 9,234         -         -
  Other                                                  7,232     5,338     4,045
     Total revenues                                    100,789    40,112    31,260
Costs and Expenses
  Cost of gas, electricity, metals and
   other products                                       94,517    34,761    26,381
  Operating expenses                                     3,184     3,045     2,473
  Depreciation, depletion and
   amortization                                            855       870       827
  Taxes, other than income taxes                           280       193       201
  Impairment of long-lived assets                            -       441         -
     Total costs and expenses                           98,836    39,310    29,882
Operating Income                                         1,953       802     1,378
Other Income and Deductions
  Equity in earnings of unconsolidated
   equity affiliates                                        87       309        97
  Gains on sales of non-merchant assets                    146       541        56
  Gain on the issuance of stock by TNPC, Inc.              121         -         -
  Interest income                                          212       162        88
  Other income, net                                        (37)      181       (37)
Income Before Interest, Minority
 Interests and Income Taxes                              2,482     1,995     1,582
Interest and related charges, net                          838       656       550
Dividends on company-obligated preferred
 securities of subsidiaries                                 77        76        77
Minority interests                                         154       135        77
Income tax expense                                         434       104       175
Net income before cumulative effect of
 accounting changes                                        979     1,024       703
Cumulative effect of accounting changes,
 net of tax                                                  -      (131)        -
Net Income                                                 979       893       703
Preferred stock dividends                                   83        66        17
Earnings on Common Stock                              $    896   $   827   $   686
Earnings Per Share of Common Stock
  Basic
     Before cumulative effect of accounting
      changes                                         $   1.22   $  1.36   $  1.07
     Cumulative effect of accounting changes                 -     (0.19)        -
       Basic earnings per share                       $   1.22   $  1.17   $  1.07
  Diluted
     Before cumulative effect of accounting
      changes                                         $   1.12   $  1.27   $  1.01
     Cumulative effect of accounting changes                 -     (0.17)        -
       Diluted earnings per share                     $   1.12   $  1.10   $  1.01
Average Number of Common Shares Used in Computation
  Basic                                                    736       705       642
  Diluted                                                  814       769       695

<FN>
The accompanying notes are an integral part of these consolidated financial
statements.
</TABLE>

<PAGE>
<TABLE>

                  ENRON CORP. AND SUBSIDIARIES
         CONSOLIDATED STATEMENT OF COMPREHENSIVE INCOME

<CAPTION>
                                       Year ended December 31,
(In millions)                          2000      1999      1998

<S>                                  <C>       <C>      <C>
Net Income                           $  979    $  893   $   703
Other comprehensive income:
  Foreign currency translation
   adjustment and other                (307)     (579)      (14)
Total Comprehensive Income           $  672    $  314   $   689

<FN>
The accompanying notes are an integral part of these consolidated
financial statements.
</TABLE>

<PAGE>
<TABLE>
                ENRON CORP. AND SUBSIDIARIES
                 CONSOLIDATED BALANCE SHEET

<CAPTION>
                                              December 31,
(In millions)                              2000         1999

<S>                                       <C>         <C>
ASSETS
Current Assets
  Cash and cash equivalents               $ 1,374     $   288
  Trade receivables (net of allowance
   for doubtful accounts of $133 and
   $40, respectively)                      10,396       3,030
  Other receivables                         1,874         518
  Assets from price risk management
   activities                              12,018       2,205
  Inventories                                 953         598
  Deposits                                  2,433          81
  Other                                     1,333         535
     Total current assets                  30,381       7,255

Investments and Other Assets
  Investments in and advances to
   unconsolidated equity affiliates         5,294       5,036
  Assets from price risk management
   activities                               8,988       2,929
  Goodwill                                  3,638       2,799
  Other                                     5,459       4,681
     Total investments and other assets    23,379      15,445

Property, Plant and Equipment, at cost
  Natural gas transmission                  6,916       6,948
  Electric generation and distribution      4,766       3,552
  Fiber optic network and equipment           839         379
  Construction in progress                    682       1,120
  Other                                     2,256       1,913
                                           15,459      13,912
  Less accumulated depreciation,
   depletion and amortization               3,716       3,231
     Property, plant and equipment, net    11,743      10,681

Total Assets                              $65,503     $33,381

<FN>
The accompanying notes are an integral part of these
consolidated financial statements.
</TABLE>


<PAGE>
<TABLE>
                ENRON CORP. AND SUBSIDIARIES
                 CONSOLIDATED BALANCE SHEET

<CAPTION>
                                                    December 31,
(In millions, except shares)                      2000         1999

<S>                                              <C>         <C>
LIABILITIES AND SHAREHOLDERS' EQUITY
Current Liabilities
  Accounts payable                               $ 9,777     $ 2,154
  Liabilities from price risk
   management activities                          10,495       1,836
  Short-term debt                                  1,679       1,001
  Customers' deposits                              4,277          44
  Other                                            2,178       1,724
     Total current liabilities                    28,406       6,759

Long-Term Debt                                     8,550       7,151

Deferred Credits and Other Liabilities
  Deferred income taxes                            1,644       1,894
  Liabilities from price risk
   management activities                           9,423       2,990
  Other                                            2,692       1,587
     Total deferred credits and
      other liabilities                           13,759       6,471
Commitments and Contingencies
 (Notes 13, 14 and 15)

Minority Interests                                 2,414       2,430

Company-Obligated Preferred Securities
 of Subsidiaries                                     904       1,000

Shareholders' Equity
  Second preferred stock, cumulative, no par
   value, 1,370,000 shares authorized,
   1,240,933 shares and 1,296,184 shares
   issued, respectively                              124         130
  Mandatorily Convertible Junior Preferred
   Stock, Series B, no par value, 250,000
   shares issued                                   1,000       1,000
  Common stock, no par value, 1,200,000,000
   shares authorized, 752,205,112 shares
   and 716,865,081 shares issued, respectively     8,348       6,637
  Retained earnings                                3,226       2,698
  Accumulated other comprehensive income          (1,048)       (741)
  Common stock held in treasury, 577,066
   shares and 1,337,714 shares,
   respectively                                      (32)        (49)
  Restricted stock and other                        (148)       (105)
     Total shareholders' equity                   11,470       9,570

Total Liabilities and Shareholders' Equity       $65,503     $33,381

<FN>
The accompanying notes are an integral part of these
consolidated financial statements.
</TABLE>


<PAGE>
<TABLE>
                       ENRON CORP. AND SUBSIDIARIES
                   CONSOLIDATED STATEMENT OF CASH FLOWS

<CAPTION>
                                                      Year ended December 31,
(In millions)                                         2000      1999      1998

<S>                                                  <C>       <C>       <C>
Cash Flows From Operating Activities
Reconciliation of net income to net
 cash provided by operating activities
  Net income                                         $   979   $   893   $   703
  Cumulative effect of accounting changes                  -       131         -
  Depreciation, depletion and amortization               855       870       827
  Impairment of long-lived assets (including
   equity investments)                                   326       441         -
  Deferred income taxes                                  207        21        87
  Gains on sales of non-merchant assets                 (146)     (541)      (82)
  Changes in components of working
   capital                                             1,769    (1,000)     (233)
  Net assets from price risk management
   activities                                           (763)     (395)      350
  Merchant assets and investments:
     Realized gains on sales                            (104)     (756)     (628)
     Proceeds from sales                               1,838     2,217     1,434
     Additions and unrealized gains                   (1,295)     (827)     (721)
  Other operating activities                           1,113       174       (97)
Net Cash Provided by Operating Activities              4,779     1,228     1,640
Cash Flows From Investing Activities
  Capital expenditures                                (2,381)   (2,363)   (1,905)
  Equity investments                                    (933)     (722)   (1,659)
  Proceeds from sales of non-merchant assets             494       294       239
  Acquisition of subsidiary stock                       (485)        -      (180)
  Business acquisitions, net of cash acquired
   (see Note 2)                                         (777)     (311)     (104)
  Other investing activities                            (182)     (405)     (356)
Net Cash Used in Investing Activities                 (4,264)   (3,507)   (3,965)
Cash Flows From Financing Activities
  Issuance of long-term debt                           3,994     1,776     1,903
  Repayment of long-term debt                         (2,337)   (1,837)     (870)
  Net increase (decrease) in short-term borrowings    (1,595)    1,565      (158)
  Net issuance (redemption) of company-obligated
   preferred securities of subsidiaries                  (96)        -         8
  Issuance of common stock                               307       852       867
  Issuance of subsidiary equity                          500       568       828
  Dividends paid                                        (523)     (467)     (414)
  Net disposition of treasury stock                      327       139        13
  Other financing activities                              (6)     (140)       89
Net Cash Provided by Financing Activities                571     2,456     2,266
Increase (Decrease) in Cash and Cash Equivalents       1,086       177       (59)
Cash and Cash Equivalents, Beginning of Year             288       111       170
Cash and Cash Equivalents, End of Year               $ 1,374   $   288   $   111

Changes in Components of Working Capital
  Receivables                                        $(8,203)  $  (662)  $(1,055)
  Inventories                                          1,336      (133)     (372)
  Payables                                             7,167      (246)      433
  Other                                                1,469        41       761
     Total                                           $ 1,769   $(1,000)  $  (233)

<FN>
The accompanying notes are an integral part of these consolidated financial
statements.
</TABLE>


<PAGE>
<TABLE>
                       ENRON CORP. AND SUBSIDIARIES
         CONSOLIDATED STATEMENT OF CHANGES IN SHAREHOLDERS' EQUITY

<CAPTION>
(In millions, except per share                   2000                1999                1998
 amounts; shares in thousands)              Shares   Amount      Shares   Amount     Shares   Amount

<S>                                       <C>        <C>       <C>        <C>      <C>        <C>
Cumulative Second Preferred
 Convertible Stock
  Balance, beginning of year                1,296    $   130     1,320    $  132     1,338    $  134
  Exchange of convertible preferred
   stock for common stock                     (55)        (6)      (24)       (2)      (18)       (2)
  Balance, end of year                      1,241    $   124     1,296    $  130     1,320    $  132
Mandatorily Convertible Junior Preferred
 Stock, Series B
  Balance, beginning of year                  250    $ 1,000         -    $    -         -    $    -
  Issuances                                     -          -       250     1,000         -         -
  Balance, end of year                        250    $ 1,000       250    $1,000         -    $    -
Common Stock
  Balance, beginning of year              716,865    $ 6,637   671,094    $5,117   636,594    $4,224
  Exchange of convertible preferred
   stock for common stock                   1,509          6       465        (1)        -        (7)
  Issuances related to benefit
   and dividend reinvestment plans         28,100        966    10,054       258         -        45
  Sales of common stock                         -          -    27,600       839    34,500       836
  Issuances of common stock in business
   acquisitions (see Note 2)                5,731        409     7,652       250         -         -
  Other                                         -        330         -       174         -        19
  Balance, end of year                    752,205    $ 8,348   716,865    $6,637   671,094    $5,117
Retained Earnings
  Balance, beginning of year                         $ 2,698              $2,226             $1,852
  Net income                                             979                 893                703
  Cash dividends
     Common stock ($0.5000, $0.5000 and
      $0.4812 per share in 2000, 1999
      and 1998, respectively)                           (368)               (355)              (312)
     Cumulative Second Preferred
      Convertible Stock ($13.652, $13.652
      and $13.1402 per share in 2000,
      1999 and 1998, respectively)                       (17)                (17)               (17)
     Series A and B Preferred Stock                      (66)                (49)                 -
  Balance, end of year                               $ 3,226              $2,698             $2,226
Accumulated Other Comprehensive Income
  Balance, beginning of year                         $  (741)             $ (162)            $ (148)
  Translation adjustments and other                     (307)               (579)               (14)
  Balance, end of year                               $(1,048)             $ (741)            $ (162)
Treasury Stock
  Balance, beginning of year               (1,338)   $   (49)   (9,334)   $ (195)  (14,102)  $ (269)
  Shares acquired                          (3,114)      (234)   (1,845)      (71)   (2,236)     (61)
  Exchange of convertible preferred
   stock for common stock                       -          -       181         4       486        9
  Issuances related to benefit
   and dividend reinvestment plans          3,875        251     9,660       213     6,426      124
  Issuances of treasury stock in
   business acquisitions                        -          -         -         -        92        2
  Balance, end of year                       (577)   $   (32)   (1,338)   $  (49)   (9,334)  $ (195)
Restricted Stock and Other
  Balance, beginning of year                         $  (105)             $  (70)            $ (175)
  Issuances related to benefit
   and dividend reinvestment plans                       (43)                (35)               105
  Balance, end of year                               $  (148)             $ (105)            $  (70)
Total Shareholders' Equity                           $11,470              $9,570             $7,048

<FN>
The accompanying notes are an integral part of these consolidated financial
statements.
</TABLE>

<PAGE>
                  ENRON CORP. AND SUBSIDIARIES
         NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS


1  SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

   Consolidation Policy and Use of Estimates.  The accounting and
financial reporting policies of Enron Corp. and its subsidiaries
conform to generally accepted accounting principles and
prevailing industry practices.  The consolidated financial
statements include the accounts of all subsidiaries controlled by
Enron Corp. after the elimination of significant intercompany
accounts and transactions.

   The preparation of financial statements in conformity with
generally accepted accounting principles requires management to
make estimates and assumptions that affect the reported amounts
of assets and liabilities and disclosure of contingent assets and
liabilities at the date of the financial statements and the
reported amounts of revenues and expenses during the reporting
period.  Actual results could differ from those estimates.

   "Enron" is used from time to time herein as a collective
reference to Enron Corp. and its subsidiaries and affiliates.
The businesses of Enron are conducted by its subsidiaries and
affiliates whose operations are managed by their respective
officers.

   Cash Equivalents.  Enron records as cash equivalents all
highly liquid short-term investments with original maturities of
three months or less.

   Inventories.  Inventories consist primarily of commodities,
priced at market as such inventories are used in trading
activities.

   Depreciation, Depletion and Amortization.  The provision for
depreciation and amortization with respect to operations other
than oil and gas producing activities is computed using the
straight-line or regulatorily mandated method, based on estimated
economic lives.  Composite depreciation rates are applied to
functional groups of property having similar economic
characteristics.  The cost of utility property units retired,
other than land, is charged to accumulated depreciation.

   Provisions for depreciation, depletion and amortization of
proved oil and gas properties are calculated using the units-of-
production method.

   Income Taxes.  Enron accounts for income taxes using an asset
and liability approach under which deferred assets and
liabilities are recognized based on anticipated future tax
consequences attributable to differences between financial
statement carrying amounts of assets and liabilities and their
respective tax bases (see Note 5).

   Earnings Per Share.  Basic earnings per share is computed
based upon the weighted-average number of common shares
outstanding during the periods.  Diluted earnings per share is
computed based upon the weighted-average number of common shares
outstanding plus the assumed issuance of common shares for all
potentially dilutive securities.  All share and per share amounts
have been adjusted to reflect the August 13, 1999 two-for-one
stock split.  See Note 11 for a reconciliation of the basic and
diluted earnings per share computations.

   Accounting for Price Risk Management.  Enron engages in price
risk management activities for both trading and non-trading
purposes.  Instruments utilized in connection with trading
activities are accounted for using the mark-to-market method.
Under the mark-to-market method of accounting, forwards, swaps,
options, energy transportation contracts utilized for trading
activities and other instruments with third parties are reflected
at fair value and are shown as "Assets and Liabilities from Price
Risk Management Activities" in the Consolidated Balance Sheet.
These activities also include the commodity risk management
component embedded in energy outsourcing contracts.  Unrealized
gains and losses from newly originated contracts, contract
restructurings and the impact of price movements are recognized
as "Other Revenues."  Changes in the assets and liabilities from
price risk management activities result primarily from changes in
the valuation of the portfolio of contracts, newly originated
transactions and the timing of settlement relative to the receipt
of cash for certain contracts.  The market prices used to value
these transactions reflect management's best estimate considering
various factors including closing exchange and over-the-counter
quotations, time value and volatility factors underlying the
commitments.

   Financial instruments are also utilized for non-trading
purposes to hedge the impact of market fluctuations on assets,
liabilities, production and other contractual commitments.  Hedge
accounting is utilized in non-trading activities when there is a
high degree of correlation between price movements in the
derivative and the item designated as being hedged.  In instances
where the anticipated correlation of price movements does not
occur, hedge accounting is terminated and future changes in the
value of the financial instruments are recognized as gains or
losses.  If the hedged item is sold, the value of the financial
instrument is recognized in income.  Gains and losses on
financial instruments used for hedging purposes are recognized in
the Consolidated Income Statement in the same manner as the
hedged item.

   The cash flow impact of financial instruments is reflected as
cash flows from operating activities in the Consolidated
Statement of Cash Flows.  See Note 3 for further discussion of
Enron's price risk management activities.

   Accounting for Development Activity.  Development costs
related to projects, including costs of feasibility studies, bid
preparation, permitting, licensing and contract negotiation, are
expensed as incurred until the project is estimated to be
probable.  At that time, such costs are capitalized or expensed
as incurred, based on the nature of the costs incurred.
Capitalized development costs may be recovered through
reimbursements from joint venture partners or other third
parties, or classified as part of the investment and recovered
through the cash flows from that project.  Accumulated
capitalized project development costs are otherwise expensed in
the period that management determines it is probable that the
costs will not be recovered.

   Environmental Expenditures.  Expenditures that relate to an
existing condition caused by past operations, and do not
contribute to current or future revenue generation, are expensed.
Environmental expenditures relating to current or future revenues
are expensed or capitalized as appropriate based on the nature of
the costs incurred.  Liabilities are recorded when environmental
assessments and/or clean-ups are probable and the costs can be
reasonably estimated.

   Computer Software.  Direct costs of materials and services
consumed in developing or obtaining software, including payroll
and payroll-related costs for employees who are directly
associated with and who devote time to the software project are
capitalized.  Costs may begin to be capitalized once the application
development stage has begun.  All other costs are expensed as
incurred.  Enron amortizes the costs on a straight-line basis
over the useful life of the software.  Impairment is evaluated
based on changes in the expected usefulness of the software.  At
December 31, 2000 and 1999, Enron has capitalized, net of
amortization, $381 million and $240 million, respectively, of
software costs covering numerous systems, including trading and
settlement, accounting, billing, and upgrades.

   Investments in Unconsolidated Affiliates.  Investments in
unconsolidated affiliates are accounted for by the equity method,
except for certain investments resulting from Enron's merchant
investment activities which are included at market value in
"Other Investments" in the Consolidated Balance Sheet. See Notes
4 and 9.  Where acquired assets are accounted for under the
equity method based on temporary control, earnings or losses are
recognized only for the portion of the investment to be retained.

   Sale of Subsidiary Stock.  Enron accounts for the issuance of stock
by its subsidiaries in accordance with the Securities and Exchange
Commission's Staff Accounting Bulletin (SAB) 51.  SAB 51 allows for
Enron to recognize a gain in the amount that the offering price
per share of a subsidiary's stock exceeds Enron's carrying amount
per share.

   Foreign Currency Translation.  For international subsidiaries,
asset and liability accounts are translated at year-end rates of
exchange and revenue and expenses are translated at average
exchange rates prevailing during the year.  For subsidiaries
whose functional currency is deemed to be other than the U.S.
dollar, translation adjustments are included as a separate
component of other comprehensive income and shareholders' equity.
Currency transaction gains and losses are recorded in income.

   During 1999, the exchange rate for the Brazilian real to the
U.S. dollar declined, resulting in a non-cash foreign currency
translation adjustment reducing the value of Enron's assets and
shareholders' equity by approximately $600 million.

   Reclassifications.  Certain reclassifications have been made
to the consolidated financial statements for prior years to
conform with the current presentation.

2  BUSINESS ACQUISITIONS AND DISPOSITIONS

   In 2000, Enron, through a wholly-owned subsidiary, acquired
all of the outstanding common shares of MG plc, a leading
independent international metals market-making business that
provides financial and marketing services to the global metals
industry, for $413 million in cash and assumed debt
of approximately $1.6 billion.

   In addition, Enron made other acquisitions including a
technology-related company, a facility maintenance company and all
minority shareholders' interests in Enron Energy Services, LLC and
Enron Renewable Energy Corp.  Enron issued 5.7 million shares of
Enron common stock, contributed common stock and warrants
of an unconsolidated equity affiliate and paid cash in these
transactions.

   On August 16, 1999, Enron exchanged approximately 62.3 million
shares (approximately 75%) of the Enron Oil & Gas Company (EOG)
common stock it held for all of the stock of EOGI-India, Inc., a
subsidiary of EOG.  Also in August 1999, Enron received net
proceeds of approximately $190 million for the sale of 8.5
million shares of EOG common stock in a public offering and
issued approximately $255 million of public debt that is
exchangeable in July 2002 into approximately 11.5 million shares
of EOG common stock.  As a result of the share exchange and share
sale, Enron recorded a pre-tax gain of $454 million ($345 million
after tax, or $0.45 per diluted share) in 1999.  As of August 16,
1999, EOG is no longer included in Enron's consolidated financial
statements.  EOGI-India, Inc. is included in the consolidated
financial statements within the Wholesale Services segment
following the exchange and sale.  Enron accounts for its oil and
gas exploration and production activities under the successful
efforts method of accounting.

   In August 1998, Enron, through a wholly-owned subsidiary,
completed the acquisition of a controlling interest in Elektro
Eletricidade e Servicos S.A. (Elektro) for approximately $1.3
billion.  Elektro was initially accounted for using the equity
method based on temporary control.  In 1999, after the acquisition
of additional interests, Elektro was consolidated by Enron.

   Additionally, during 1999 and 1998, Enron acquired generation,
natural gas distribution, renewable energy, telecommunications
and energy management businesses for cash, Enron and subsidiary
stock and notes.

   Enron has accounted for these acquisitions using the purchase
method of accounting as of the effective date of each
transaction. Accordingly, the purchase price of each transaction
has been allocated based upon the estimated fair value of the
assets and liabilities acquired as of the acquisition date, with
the excess reflected as goodwill in the Consolidated Balance
Sheet. This and all other goodwill is being amortized on a
straight-line basis over 5 to 40 years.

   Assets acquired, liabilities assumed and consideration paid as
a result of businesses acquired were as follows:

<TABLE>
<CAPTION>
(In millions)                          2000      1999      1998(a)

<S>                                  <C>        <C>        <C>
Fair value of assets acquired,
 other than cash                     $ 2,641    $  376     $ 269
Goodwill                                 963       (71)       94
Fair value of liabilities assumed     (2,418)        6      (259)
Common stock of Enron issued
 and equity of an unconcolidated
 equity affiliate contributed           (409)        -         -
Net cash paid                        $   777    $  311     $ 104

<FN>
(a) Excludes amounts related to the 1998 acquisition of Elektro.
</TABLE>

   On November 8, 1999, Enron announced that it had entered into
an agreement to sell Enron's wholly-owned electric utility
subsidiary, Portland General Electric Company (PGE), to Sierra
Pacific Resources for $2.1 billion. Sierra Pacific Resources will
also assume approximately $1 billion in PGE debt and preferred
stock. The transaction has been delayed by the effect of recent
events in California and Nevada on the buyer. Enron's
carrying amount of PGE as of December 31, 2000 was approximately
$1.6 billion. Income before interest, minority interest and
income taxes for PGE was $338 million, $298 million and $284
million for 2000, 1999 and 1998, respectively.

3  PRICE RISK MANAGEMENT ACTIVITIES AND FINANCIAL INSTRUMENTS

   Trading Activities.  Enron offers price risk management
services to wholesale, commercial and industrial customers
through a variety of financial and other instruments including
forward contracts involving physical delivery, swap agreements,
which require payments to (or receipt of payments from)
counterparties based on the differential between a fixed and
variable price for the commodity, options and other contractual
arrangements.  Interest rate risks and foreign currency risks
associated with the fair value of the commodity portfolio are
managed using a variety of financial instruments, including
financial futures.

   Notional Amounts and Terms.  The notional amounts and terms of
these instruments at December 31, 2000 are shown below (dollars
in millions):

<TABLE>
<CAPTION>
                            Fixed Price   Fixed Price      Maximum
                               Payor       Receiver     Terms in Years

<S>                           <C>           <C>               <C>
Commodities(a)
  Natural gas                  7,331         6,910            23
  Crude oil and liquids        3,513         1,990             6
  Electricity                  2,424         2,388            24
  Metals, coal and pulp
   and paper                     368           413             9
  Bandwidth                      167           325            11
Financial products
  Interest rate(b)            $4,732        $3,977            29
  Foreign currency            $   79        $  465            22
  Equity investments(c)       $2,998        $3,768            13

<FN>
(a)  Natural gas, crude oil and liquids and electricity
     volumes are in TBtue; metals, coal and pulp and paper
     volumes are in millions of metric tonnes; and bandwidth
     volumes are in thousands of terabytes.
(b)  The interest rate fixed price receiver includes the net
     notional dollar value of the interest rate sensitive component
     of the combined commodity portfolio.  The remaining interest
     rate fixed price receiver and the entire interest rate fixed
     price payor represent the notional contract amount of a
     portfolio of various financial instruments used to hedge the
     net present value of the commodity portfolio.  For a given
     unit of price protection, different financial instruments
     require different notional amounts.
(c)  Excludes derivatives on Enron common stock.  See Notes 10 and 11.
</TABLE>

   Enron also has sales and purchase commitments associated with
commodity contracts based on market prices totaling 8,169 TBtue,
with terms extending up to 16 years, and 7.2 million metric
tonnes, with terms extending up to 5 years.

   Notional amounts reflect the volume of transactions but do not
represent the amounts exchanged by the parties to the financial
instruments.  Accordingly, notional amounts do not accurately
measure Enron's exposure to market or credit risks.  The maximum
terms in years detailed above are not indicative of likely future
cash flows as these positions may be offset in the markets at any
time in response to the company's price risk management needs to
the extent available in the market.

   The volumetric weighted average maturity of Enron's fixed
price portfolio as of December 31, 2000 was approximately 1.5
years.

   Fair Value.  The fair value as of December 31, 2000 and the
average fair value of instruments related to price risk
management activities held during the year are set forth below:

<TABLE>
<CAPTION>
                                                 Average Fair Value
                              Fair Value         for the Year Ended
                            as of 12/31/00           12/31/00(a)
(In millions)            Assets    Liabilities   Assets   Liabilities

<S>                     <C>          <C>        <C>         <C>
Natural gas             $10,270      $ 9,342    $ 5,525     $ 5,114
Crude oil and liquids     1,549        3,574      1,402       2,745
Electricity               7,335        5,396      3,453       1,613
Other commodities         1,509        1,311        988         757
Equity investments          795          295        492         280
  Total                 $21,458      $19,918    $11,860     $10,509

<FN>
(a)  Computed using the ending balance at each month-end.
</TABLE>

   The income before interest, taxes and certain unallocated
expenses arising from price risk management activities for 2000
was $1,899 million.

   Securitizations.  From time to time, Enron sells interests
in certain of its financial assets.  Some of these sales
are completed in securitizations, in which Enron concurrently
enters into swaps associated with the underlying assets which
limits the risks assumed by the purchaser.  Such swaps are
adjusted to fair value using quoted market prices, if available,
or estimated fair value based on management's best estimate of
the present value of future cash flow.  These swaps are included
in Price Risk Management activities above as equity investments.
During 2000, gains from sales representing securitizations were
$381 million and proceeds were $2,379 million ($545 million of
the proceeds related to sales to Whitewing Associates, L.P.
(Whitewing)).  See Notes 4 and 9.  Purchases of securitized
merchant financial assets totaled $1,184 million during 2000.
Amounts primarily related to equity interests.

   Credit Risk.  In conjunction with the valuation of its
financial instruments, Enron provides reserves for credit risks
associated with such activity.  Credit risk relates to the risk
of loss that Enron would incur as a result of nonperformance by
counterparties pursuant to the terms of their contractual
obligations.  Enron maintains credit policies with regard to its
counterparties that management believes significantly minimize
overall credit risk.  These policies include an evaluation of
potential counterparties' financial condition (including credit
rating), collateral requirements under certain circumstances and
the use of standardized agreements which allow for the netting of
positive and negative exposures associated with a single
counterparty.  Enron also minimizes this credit exposure using
monetization of its contract portfolio or third-party insurance
contracts.  The counterparties associated with assets from price
risk management activities as of December 31, 2000 and 1999 are
summarized as follows:

<TABLE>
<CAPTION>
                                    2000                1999
                             Investment          Investment
(In millions)                 Grade(a)   Total    Grade(a)   Total

<S>                           <C>       <C>        <C>      <C>
Gas and electric utilities    $ 5,050   $ 5,327    $1,461   $1,510
Energy marketers                4,677     6,124       544      768
Financial institutions          4,145     4,917     1,016    1,273
Independent power producers       672       791       471      641
Oil and gas producers           1,308     2,804       379      688
Industrials                       607     1,138       336      524
Other                             256       357        59       67
  Total                       $16,715    21,458    $4,266    5,471
Credit and other reserves                  (452)              (337)
Assets from price risk
 management activities(b)               $21,006(c)          $5,134

<FN>
(a) "Investment Grade" is primarily determined using publicly
    available credit ratings along with consideration of cash,
    standby letters of credit, parent company guarantees and
    property interests, including oil and gas reserves.  Included
    in "Investment Grade" are counterparties with a minimum
    Standard & Poor's or Moody's rating of BBB- or Baa3, respectively.
(b) One and two customers' exposures, respectively, at
    December 31, 2000 and 1999 comprise greater than 5% of Assets
    From Price Risk Management Activities and are included above
    as Investment Grade.
(c) At December 31, 2000, Enron held collateral of approximately
    $5.5 billion, which consists substantially of cash deposits shown
    as "Customers' Deposits" on the balance sheet.
</TABLE>

   This concentration of counterparties may impact Enron's
overall exposure to credit risk, either positively or negatively,
in that the counterparties may be similarly affected by changes
in economic, regulatory or other conditions.  Based on Enron's
policies, its exposures and its credit reserves, Enron
does not anticipate a materially adverse effect on financial
position or results of operations as a result of counterparty
nonperformance.

   During 2000, the California power market was significantly
impacted by the increase in wholesale power prices.  California
customer rates are currently frozen, requiring the utilities to
finance the majority of their power purchases.  If wholesale
prices remain at the current levels and no regulatory relief or
legislative assistance is obtained, certain California utilities
may need to seek bankruptcy protection.  During 2000, Enron
entered into wholesale power transactions with California
utilities, including their nonregulated power marketing
affiliates.  Enron has provided credit reserves related to such
activities based on Enron's net position with each California
utility.  Due to the uncertainties surrounding the California
power situation, management cannot predict the ultimate outcome
but believes these matters will not have a material adverse
impact on Enron's financial condition.

   Non-Trading Activities.  Enron also enters into financial
instruments such as swaps and other contracts primarily for the
purpose of hedging the impact of market fluctuations on assets,
liabilities, production or other contractual commitments.

   Energy Commodity Price Swaps.  At December 31, 2000, Enron was
a party to energy commodity price swaps covering 18.6 TBtu, 29.9
TBtu and 0.5 TBtu of natural gas for the years 2001, 2002 and
2003, respectively, and 0.3 million barrels of crude oil for the
year 2001.

   Interest Rate Swaps.  At December 31, 2000, Enron had entered
into interest rate swap agreements with an aggregate notional
principal amount of $1.0 billion to manage interest rate
exposure.  These swap agreements are scheduled to terminate $0.4
billion in 2001 and $0.6 billion in the period 2002 through 2010.

   Foreign Currency Contracts.  At December 31, 2000, foreign
currency contracts with a notional principal amount of $1.4
billion were outstanding.  These contracts will expire $1.0
billion in 2001 and $0.4 billion in the period 2002 through 2006.

   Equity Contracts.  At December 31, 2000, Enron had entered
into Enron common stock swaps, with an aggregate notional amount
of $121 million, to hedge certain incentive-based compensation
plans.  Such contracts will expire in 2001.

   Credit Risk.  While notional amounts are used to express the
volume of various financial instruments, the amounts potentially
subject to credit risk, in the event of nonperformance by the
third parties, are substantially smaller.  Forwards, futures and
other contracts are entered into with counterparties who are equivalent
to investment grade.  Accordingly, Enron does not anticipate any
material impact to its financial position or results of
operations as a result of nonperformance by the third parties on
financial instruments related to non-trading activities.

   Financial Instruments.  The carrying amounts and estimated
fair values of Enron's financial instruments, excluding trading
activities, at December 31, 2000 and 1999 were as follows:

<TABLE>
<CAPTION>
                                     2000                    1999
                              Carrying   Estimated    Carrying   Estimated
(In millions)                  Amount    Fair Value    Amount    Fair Value

<S>                           <C>         <C>          <C>        <C>
Short- and long-term debt
 (Note 7)                     $10,229     $10,217      $8,152     $8,108
Company-obligated preferred
 securities of subsidiaries
 (Note 10)                        904         920       1,000        937
Energy commodity price swaps        -          68           -         (3)
Interest rate swaps                 -           1           -        (55)
Foreign currency contracts          -          94           -          -
Equity contracts                   15          15           4          4
</TABLE>

   Enron uses the following methods and assumptions in estimating
fair values: (a) short- and long-term debt - the carrying amount
of variable-rate debt approximates fair value, the fair value of
marketable debt is based on quoted market prices and the fair
value of other debt is based on the discounted present value of
cash flows using Enron's current borrowing rates; (b) company-
obligated preferred securities of subsidiaries - the fair value
is based on quoted market prices, where available, or based on
the discounted present value of cash flows using Enron's current
borrowing rates if not publicly traded; and (c) energy commodity
price swaps, interest rate swaps, foreign currency contracts and
equity contracts - estimated fair values have been determined
using available market data and valuation methodologies.  Judgment
is necessarily required in interpreting market data and the use of
different market assumptions or estimation methodologies may affect
the estimated fair value amounts.

   The fair market value of cash and cash equivalents, trade and
other receivables, accounts payable and investments accounted for
at fair value are not materially different from their carrying
amounts.

   Guarantees of liabilities of unconsolidated entities and
residual value guarantees have no carrying value and fair values
which are not readily determinable (see Note 15).


4  MERCHANT ACTIVITIES

   An analysis of the composition of Enron's merchant investments
and energy assets at December 31, 2000 and 1999 is as follows:

<TABLE>
<CAPTION>
                                                December 31,
(In millions)                                  2000     1999

<S>                                           <C>      <C>
Merchant investments(a)
  Energy                                      $  137   $  516
  Energy-intensive industries                     63      218
  Technology-related                              99       11
  Other                                          302      341
                                                 601    1,086
Merchant assets(b)
  Independent power plants                        53      152
  Natural gas transportation                      36       35
                                                  89      187

Total                                         $  690   $1,273

<FN>
(a) Investments are recorded at fair value in "Other Assets"
    with changes in fair value reflected in "Other Revenues."
(b) Amounts represent Enron's investment in unconsolidated
    equity affiliates with operating earnings reflected in "Equity
    in Earnings of Unconsolidated Equity Affiliates."
</TABLE>

   Enron provides capital primarily to energy and technology-related
businesses seeking debt or equity financing.  The merchant investments
made by Enron and certain of its unconsolidated affiliates (see Note 9)
are carried at fair value and include public and private equity,
government securities with maturities of more than 90 days, debt and
interests in limited partnerships. The valuation methodologies
utilize market values of publicly-traded securities, independent
appraisals and cash flow analyses.

   Also included in Enron's wholesale business are investments in
merchant assets such as power plants and natural gas pipelines,
primarily held through equity method investments.  Some of these
assets were developed, constructed and operated by Enron.  The
merchant assets are not expected to be long-term, integrated
components of Enron's energy networks.

   For the years ended December 31, 2000, 1999 and 1998,
respectively, pre-tax gains from sales of merchant assets and
investments totaling $104 million, $756 million and $628 million
are included in "Other Revenues," and proceeds were $1,838
million, $2,217 million and $1,434 million.

5  INCOME TAXES

   The components of income before income taxes are as follows:

<TABLE>
<CAPTION>
(In millions)                  2000    1999    1998

<S>                          <C>      <C>      <C>
United States                $  640   $  357   $197
Foreign                         773      771    681
                             $1,413   $1,128   $878
</TABLE>

   Total income tax expense is summarized as follows:

<TABLE>
<CAPTION>
(In millions)                  2000    1999   1998

<S>                            <C>    <C>     <C>
Payable currently
  Federal                      $112   $ 29    $ 30
  State                          22      6       8
  Foreign                        93     48      50
                                227     83      88
Payment deferred
  Federal                        13   (159)    (14)
  State                          14     23      11
  Foreign                       180    157      90
                                207     21      87
Total income tax expense(a)    $434   $104    $175

<FN>
(a)  See Note 11 for tax benefits related to stock options
     exercised by employees reflected in shareholders'
     equity.
</TABLE>

   The differences between taxes computed at the U.S. federal
statutory tax rate and Enron's effective income tax rate are as
follows:

<TABLE>
<CAPTION>
                                  2000      1999     1998

<S>                                  <C>      <C>      <C>
Statutory federal income tax
 provision                           35.0%    35.0%    35.0%
Net state income taxes                2.5      1.8      1.7
Foreign tax rate differential        (2.4)    (7.0)     0.8
Equity earnings                       5.3    (10.1)    (4.3)
Basis and stock sale differences    (11.9)   (10.8)   (14.2)
Goodwill amortization                 1.6      1.6      2.0
Audit settlement related to Monthly
 Income Preferred Shares                -     (1.8)       -
Other                                 0.6      0.5     (1.0)
                                     30.7%     9.2%    20.0%
</TABLE>

   The principal components of Enron's net deferred income tax
liability are as follows:

<TABLE>
<CAPTION>
                                           December 31,
(In millions)                             2000      1999

<S>                                      <C>       <C>
Deferred income tax assets
  Alternative minimum tax credit
   carryforward                          $  254    $  220
  Net operating loss carryforward           369     1,302
  Other                                     189       188
                                            812     1,710
Deferred income tax liabilities
  Depreciation, depletion and
   amortization                          1,813      1,807
  Price risk management activities        (182)     1,133
  Other                                     963       782
                                          2,594     3,722
Net deferred income tax liabilities(a)   $1,782    $2,012

<FN>
(a) Includes $138 million and $118 million in other current
    liabilities for 2000 and 1999, respectively.
</TABLE>

   Enron has an alternative minimum tax (AMT) credit carryforward
of approximately $254 million which can be used to offset regular
income taxes payable in future years.  The AMT credit has an
indefinite carryforward period.

   Enron has a net operating loss carryforward applicable to U.S.
subsidiaries of approximately $65 million, which will begin to
expire in 2011.  Enron has a net operating loss carryforward
applicable to non-U.S. subsidiaries of approximately $1.2
billion, of which $1.0 billion can be carried forward
indefinitely.  The remaining $200 million expires between the
years 2001 and 2010.  Deferred tax assets have been recognized
on the $65 million domestic loss and $1.0 billion of the foreign
losses.

   U.S. and foreign income taxes have been provided for earnings
of foreign subsidiary companies that are expected to be remitted
to the U.S.  Foreign subsidiaries' cumulative undistributed
earnings of approximately $1.8 billion are considered to be
permanently reinvested outside the U.S. and, accordingly, no U.S.
income taxes have been provided thereon.  In the event of a
distribution of those earnings in the form of dividends, Enron
may be subject to both foreign withholding taxes and U.S. income
taxes net of allowable foreign tax credits.

6  SUPPLEMENTAL CASH FLOW INFORMATION

   Cash paid for income taxes and interest expense, including
fees incurred on sales of accounts receivable, is as follows:

<TABLE>
<CAPTION>
(In millions)                           2000      1999      1998

<S>                                     <C>       <C>       <C>
Income taxes (net of refunds)           $ 62      $ 51      $ 73
Interest (net of amounts capitalized)    834       678       585
</TABLE>

   Non-Cash Activity.  In 2000, Enron acquired all minority
shareholders' interests in Enron Energy Services, LLC and other
businesses with Enron common stock.  See Note 2.

   In 2000 and 1999, Enron entered into various transactions with
related parties, which resulted in an exchange of assets and an
increase in common stock of $171 million in 2000.  See Note 16.

   In 2000, a partnership in which Enron was a limited partner
made a liquidating distribution to Enron resulting in a non-cash
increase in current assets of $220 million, a decrease of $20 million
in non-current assets and an increase in current liabilities of
$160 million.

   During 2000 and 1999, Enron received the rights to specific
third-party fiber optic cable in exchange for the rights on
specific fiber optic cable held for sale by Enron.  These
exchanges resulted in non-cash increases in assets of $69
million and $111 million, respectively.

   During 1999, Enron issued approximately 7.6 million shares of
common stock in connection with the acquisition, by an unconsolidated
equity affiliate, of interests in three power plants in New Jersey.

   In December 1998, Enron extinguished its 6.25% Exchangeable
Notes with 10.5 million shares of EOG common stock.

7  CREDIT FACILITIES AND DEBT

   Enron has credit facilities with domestic and foreign banks
which provide for an aggregate of $1.4 billion in long-term
committed credit, of which $150 million relates to Portland
General, and $2.4 billion in short-term committed credit.
Expiration dates of the committed facilities range from February
2001 to May 2005.  Interest rates on borrowings are based upon
the London Interbank Offered Rate, certificate of deposit rates
or other short-term interest rates.  Certain credit facilities
contain covenants which must be met to borrow funds.  Such debt
covenants are not anticipated to materially restrict Enron's
ability to borrow funds under such facilities.  Compensating
balances are not required, but Enron is required to pay a
commitment or facility fee.  At December 31, 2000, $290 million
was outstanding under these facilities.

   Enron has also entered into agreements which provide for
uncommitted lines of credit totaling $420 million at December 31,
2000.  The uncommitted lines have no stated expiration dates.
Neither compensating balances nor commitment fees are required,
as borrowings under the uncommitted credit lines are available
subject to agreement by the participating banks.  At December 31,
2000, no amounts were outstanding under the uncommitted lines.

   In addition to borrowing from banks on a short-term basis,
Enron and certain of its subsidiaries sell commercial paper to
provide financing for various corporate purposes.  As of December
31, 2000 and 1999, short-term borrowings of $15 million and $330
million, respectively, and long-term debt due within one year of
$1,303 million and $670 million, respectively, have been
reclassified as long-term debt based upon the availability of
committed credit facilities with expiration dates exceeding
one year and management's intent to maintain such amounts in
excess of one year.  Weighted average interest rates on
short-term debt outstanding at December 31, 2000 and 1999 were
6.9% and 6.4%, respectively.

   Detailed information on long-term debt is as follows:

<TABLE>
<CAPTION>
                                              December 31,
(In millions)                                2000      1999

<S>                                         <C>       <C>
Enron Corp.
  Senior debentures
     6.75% to 8.25% due 2005 to 2012        $  262    $  318
  Notes payable(a)
     7.00% exchangeable notes due 2002         532       239
     6.40% to 9.88% due 2001 to 2028         4,416     4,114
     Floating rate notes due 2000 to 2005       92        79
     Other                                     242        34
Northern Natural Gas Company
  Notes payable
     6.75% to 7.00% due 2005 to 2011           500       500
Transwestern Pipeline Company
  Notes payable
     9.20% due 2004                             11        15
Portland General
  First mortgage bonds
     6.47% to 9.46% due 2000 to 2023           328       373
  Pollution control bonds
     Various rates due 2010 to 2033            200       200
  Other                                        282       129
Other                                          414       204
Amount reclassified from short-term debt     1,318     1,000
Unamortized debt discount and premium          (47)      (54)
Total long-term debt                        $8,550    $7,151

<FN>
(a) Includes debt denominated in foreign currencies of approximately
    $955 million and $525 million, respectively, at December 31,
    2000 and 1999.  Enron has entered into derivative transactions
    to hedge interest rates and foreign currency exchange fluctuations
    associated with such debt.  See Note 3.
</TABLE>

   The indenture securing Portland General's First Mortgage Bonds
constitutes a direct first mortgage lien on substantially all
electric utility property and franchises, other than expressly
excepted property.

   The aggregate annual maturities of long-term debt outstanding
at December 31, 2000 were $2,112 million, $750 million, $852
million, $646 million and $1,592 million for 2001 through 2005,
respectively.

   In February 2001, Enron issued $1.25 billion zero coupon
convertible senior notes that mature in 2021.  The notes carry a
2.125 percent yield to maturity with an aggregate face value of $1.9
billion and may be converted, upon certain contingencies being met,
into Enron common stock at an initial conversion premium of 45 percent.

8  MINORITY INTERESTS

   Enron's minority interests at December 31, 2000 and 1999
include the following:

<TABLE>
<CAPTION>
(In millions)                            2000     1999

<S>                                    <C>       <C>
Majority-owned limited liability
 company and limited partnerships      $1,759    $1,773
Elektro(a)                                462       475
Other                                     193       182
                                       $2,414    $2,430

<FN>
(a) Relates to the respective parents of Elektro, which
    had minority shareholders in 2000 and 1999.
</TABLE>

   Enron has formed separate limited partnerships and a limited
liability company with third-party investors for various
purposes.  These entities are included in Enron's consolidated
financial statements, with the third-party investors' interests
reflected in "Minority Interests" in the Consolidated Balance
Sheet.

   In October 2000, Enron contributed approximately $1.0 billion
of net assets to a wholly-owned limited liability company.  A
third party contributed $500 million for a preferred membership
interest in the limited liability company.  The contribution by
the third party was invested in highly liquid investment grade
securities (including Enron notes) and short-term receivables.
At December 31, 2000, the majority-owned limited liability company
held net assets of $1.0 billion.

   During 1999, third-party investors contributed cash and
merchant investments totaling $1.0 billion to Enron-sponsored
entities to invest in highly liquid investment grade securities
(including Enron notes) and short-term receivables.  The merchant
investments, totaling $500 million, were sold prior to December
31, 1999.  During 2000, Enron acquired a portion of the minority
shareholder's interest for $485 million.

   In 1998, Enron formed a wholly-owned limited partnership for
the purpose of holding $1.6 billion of assets contributed by
Enron.  That partnership contributed $850 million of assets and a
third party contributed $750 million to a second newly-formed
limited partnership.  The assets held by the wholly-owned limited
partnership represent collateral for a $750 million note
receivable held by the second limited partnership.  In 2000 and
1999, the wholly-owned and second limited partnerships sold
assets valued at approximately $152 million and $460 million,
respectively, and invested the proceeds in Enron notes.

   Absent certain defaults or other specified events, Enron has
the option to acquire the minority holders' interests in these
partnerships.  Enron has the option to acquire the minority
holders' interest in the limited liability company after
November 2002.  If Enron does not acquire the minority holders'
interests before December 2004 through May 2009, or earlier upon
certain specified events, the minority interest holders may cause
the entities to liquidate their assets and dissolve.

   In 2000, as part of a restructuring, Jacare Electrical
Distribution Trust (Jacare) sold a 47 percent interest in Enron
Brazil Power Holdings V Ltd, a subsidiary that holds its
investment in Elektro, to Whitewing for approximately $460 million.
See Note 9.  The proceeds were used to acquire the original minority
shareholder's interest in Jacare.

   In 2000, Enron acquired all minority shareholders' interests
in Enron Energy Services, LLC and Enron Renewable Energy Corp.
See Note 2.

9  UNCONSOLIDATED EQUITY AFFILIATES

   Enron's investment in and advances to unconsolidated
affiliates which are accounted for by the equity method is as
follows:

<TABLE>
<CAPTION>
                                      Net
                                     Voting         December 31,
(In millions)                       Interest(a)    2000       1999

<S>                                   <C>        <C>         <C>
Azurix Corp.                          34%        $  325      $  762
Bridgeline Holdings                   40%           229           -
Citrus Corp.                          50%           530         480
Dabhol Power Company                  50%           693         466
Joint Energy Development Investments
 L.P. (JEDI)(b)                       50%           399         211
Joint Energy Development Investments
 II L.P. (JEDI II)(b)                 50%           220         162
SK - Enron Co. Ltd.                   50%           258         269
Transportadora de Gas del Sur S.A.    35%           479         452
Whitewing Associates, L.P.(b)         50%           558         662
Other                                             1,603       1,572
                                                 $5,294(c)   $5,036(c)

<FN>
(a) Certain investments have income sharing ratios which differ
    from Enron's voting interests.
(b) JEDI and JEDI II account for their investments at fair
    value.  Whitewing accounts for certain of its investments at
    fair value.  These affiliates held fair value investments
    totaling $1,823 million and $1,128 million, respectively,
    at December 31, 2000 and 1999.
(c) At December 31, 2000 and 1999, the unamortized excess of
    Enron's investment in unconsolidated affiliates was $182
    million and $179 million, respectively, which is being
    amortized over the expected lives of the investments.
</TABLE>

   Enron's equity in earnings (losses) of unconsolidated equity
affiliates is as follows:

<TABLE>
<CAPTION>
(In millions)                                   2000   1999   1998

<S>                                            <C>     <C>    <C>
Azurix Corp.(a)                                $(428)  $ 23   $  6
Citrus Corp.                                      50     25     23
Dabhol Power Company                              51     30      -
Joint Energy Development Investments L.P.        197     11    (45)
Joint Energy Development Investments II, L.P.     58     92     (4)
TNPC, Inc. (The New Power Company)               (60)     -      -
Transportadora de Gas del Sur S.A.                38     32     36
Whitewing Associates, L.P.                        58      9      -
Other                                            123     87     81
                                                $ 87   $309   $ 97

<FN>
(a) During the fourth quarter of 2000, Azurix Corp. (Azurix) impaired
    the carrying value of its Argentine assets, resulting in a charge
    of approximately $470 million.  Enron's portion of the charge was
    $326 million.
</TABLE>

   Summarized combined financial information of Enron's
unconsolidated affiliates is presented below:

<TABLE>
<CAPTION>
                                           December 31,
(In millions)                           2000         1999

<S>                                    <C>          <C>
Balance sheet
  Current assets(a)                    $ 5,884      $ 3,168
  Property, plant and equipment, net    14,786       14,356
  Other noncurrent assets               13,485        9,459
  Current liabilities(a)                 4,739        4,401
  Long-term debt(a)                      9,717        8,486
  Other noncurrent liabilities           6,148        2,402
  Owners' equity                        13,551       11,694

<FN>
(a) Includes $410 million and $327 million receivable from
    Enron and $302 million and $84 million payable to Enron at
    December 31, 2000 and 1999, respectively.
</TABLE>

<TABLE>
<CAPTION>
(In millions)                   2000      1999      1998

<S>                           <C>       <C>        <C>
Income statement(a)
  Operating revenues          $15,903   $11,568    $8,508
  Operating expenses           14,710     9,449     7,244
  Net income                      586     1,857       142
Distributions paid to Enron       137       482        87

<FN>
(a) Enron recognized revenues from transactions with
    unconsolidated equity affiliates of $510 million in 2000,
    $674 million in 1999 and $563 million in 1998.
</TABLE>

   In 2000 and 1999, Enron sold approximately $632 million and
$192 million, respectively, of merchant investments and other
assets to Whitewing.  Enron recognized no gains or losses in
connection with these transactions.  Additionally, in 2000, ECT
Merchant Investments Corp., a wholly-owned Enron subsidiary,
contributed two pools of merchant investments to a limited
partnership that is a subsidiary of Enron.  Subsequent to the
contributions, the partnership issued partnership interests
representing 100% of the beneficial, economic interests in the
two asset pools, and such interests were sold for a total of $545
million to a limited liability company that is a subsidiary of
Whitewing.  See Note 3.  These entities are separate legal entities
from Enron and have separate assets and liabilities.  In 2000 and 1999,
the Related Party, as described in Note 16, contributed $33 million
and $15 million, respectively, of equity to Whitewing.  In 2000,
Whitewing contributed $7.1 million to a partnership formed by Enron,
Whitewing and a third party.  Subsequently, Enron sold a portion of
its interest in the partnership through a securitization.  See Note 3.

   In 2000, The New Power Company sold warrants convertible into
common stock of The New Power Company for $50 million to the
Related Party (described in Note 16).

   From time to time, Enron has entered into various
administrative service, management, construction, supply and
operating agreements with its unconsolidated equity affiliates.
Enron's management believes that its existing agreements and
transactions are reasonable compared to those which could have
been obtained from third parties.

10  PREFERRED STOCK

   Preferred Stock.  Enron has authorized 16,500,000 shares of
preferred stock, no par value.  At December 31, 2000, Enron had
outstanding 1,240,933 shares of Cumulative Second Preferred
Convertible Stock (the Convertible Preferred Stock), no par
value.  The Convertible Preferred Stock pays dividends at an
amount equal to the higher of $10.50 per share or the equivalent
dividend that would be paid if shares of the Convertible
Preferred Stock were converted to common stock.  Each share of
the Convertible Preferred Stock is convertible at any time at the
option of the holder thereof into 27.304 shares of Enron's common
stock, subject to certain adjustments.  The Convertible Preferred
Stock is currently subject to redemption at Enron's option at a
price of $100 per share plus accrued dividends.  During 2000,
1999 and 1998, 55,251 shares, 23,664 shares and 17,797 shares,
respectively, of the Convertible Preferred Stock were converted
into common stock.

   In 1999, all outstanding shares of Series A Preferred Stock
held by Whitewing were exchanged for 250,000 shares of Enron
Mandatorily Convertible Junior Preferred Stock, Series B (Series
B Preferred Stock).  Also in 1999, Enron entered into a Share
Settlement Agreement under which Enron could be obligated, under
certain circumstances, to deliver additional shares of common
stock or Series B Preferred Stock to Whitewing for the amount
that the market price of the converted Enron common shares is
less than $28 per share.  In 2000, Enron increased the strike
price in the Share Settlement Agreement to $48.55 per share in
exchange for an additional capital contribution in Whitewing by
third-party investors.  The number of shares of Series B
Preferred Stock authorized equals the number of shares necessary
to satisfy Enron's obligation under the Share Settlement
Agreement.  Absent certain defaults or other specified events,
Enron has the option to acquire the third-party investors'
interests.  If Enron does not acquire the third-party investors'
interests before January 2003, or earlier upon certain specified
events, Whitewing may liquidate its assets and dissolve.  At
December 31, 2000, Enron had outstanding 250,000 shares of Series
B Preferred Stock with a liquidation value of $1.0 billion.  The
Series B Preferred Stock pays semi-annual cash dividends at an
annual rate of 6.50%.  Each share of Series B Preferred Stock is
mandatorily convertible into 200 shares of Enron common stock on
January 15, 2003 or earlier upon the occurrence of certain
events.

   In connection with the 1998 financial restructuring (yielding
proceeds of approximately $1.2 billion) of Enron's investment in
Azurix, Enron committed to cause the sale of Enron convertible
preferred stock, if certain debt obligations of the related
entity which acquired an interest in Azurix, are defaulted
upon, or in certain events, including, among other things,
Enron's credit ratings fall below specified levels.  If the sale
of the convertible preferred stock is not sufficient to retire
such obligations, Enron would be liable for the shortfall.  Such
obligations will mature in December 2001.  The number of common
shares issuable upon conversion is based on future common stock
prices.

   Company-Obligated Preferred Securities of Subsidiaries.
Summarized information for Enron's company-obligated preferred
securities of subsidiaries is as follows:

<TABLE>
<CAPTION>
                                                                      Liquidation
(In millions, except per share amounts               December 31,        Value
 and shares)                                        2000      1999     Per Share

<S>                                                <C>       <C>       <C>
Enron Capital LLC
  8% Cumulative Guaranteed Monthly Income
   Preferred Shares (8,550,000 shares)(a)          $  214    $  214    $     25

Enron Capital Trust I
  8.3% Trust Originated Preferred Securities
   (8,000,000 preferred securities)(a)                200       200          25

Enron Capital Trust II
  8 1/8% Trust Originated Preferred Securities
   (6,000,000 preferred securities)(a)                150       150          25

Enron Capital Trust III
  Adjustable-Rate Capital Trust Securities
   (200,000 preferred securities)                       -       200       1,000

LNG Power II L.L.C.
  6.74% Preference Units (105,000 shares)(b)          105         -       1,000

Enron Equity Corp.
  8.57% Preferred Stock (880 shares)(a)                88        88     100,000
  7.39% Preferred Stock (150 shares)(a)(c)             15        15     100,000

Enron Capital Resources, L.P.
  9% Cumulative Preferred Securities, Series A
   (3,000,000 preferred securities)(a)                 75        75          25

Other                                                  57        58
                                                   $  904    $1,000

<FN>
(a) Redeemable under certain circumstances after specified
    dates.
(b) Initial rate is 6.74% increasing to 7.79%.
(c) Mandatorily redeemable in 2006.
</TABLE>

11  COMMON STOCK

   Earnings Per Share.  The computation of basic and diluted
earnings per share is as follows:

<TABLE>
<CAPTION>
                                            Year Ended December 31,
(In millions, except per share amounts)     2000     1999      1998

<S>                                        <C>      <C>       <C>
Numerator:
  Basic
     Income before cumulative effect
      of accounting changes                $  979   $1,024    $  703
     Preferred stock dividends:
       Second Preferred Stock                 (17)     (17)      (17)
       Series A Preferred Stock                 -      (30)        -
       Series B Preferred Stock               (66)     (19)        -
     Income available to common share-
      holders before cumulative effect
      of accounting changes                   896      958       686
     Cumulative effect of accounting
      changes                                   -     (131)        -
     Income available to common
      shareholders                         $  896   $  827    $  686
  Diluted
     Income available to common share-
      holders before cumulative effect
      of accounting changes                $  896   $  958    $  686
     Effect of assumed conversion of
      dilutive securities(a):
       Second Preferred Stock                  17       17        17
     Income before cumulative effect
      of accounting changes                   913      975       703
     Cumulative effect of accounting
      changes                                   -     (131)        -
     Income available to common share-
      holders after assumed conversions    $  913   $  844    $  703
Denominator:
  Denominator for basic earnings per
   share - weighted-average shares            736      705       642
  Effect of dilutive securities:
     Preferred stock                           35       36        36
     Stock options                             43       28        17
  Dilutive potential common shares             78       64        53
  Denominator for diluted earnings per
   share - adjusted weighted-average
   shares and assumed conversions             814      769       695
Basic earnings per share:
  Before cumulative effect of accounting
   changes                                  $1.22    $1.36     $1.07
  Cumulative effect of accounting changes       -    (0.19)        -
  Basic earnings per share                  $1.22    $1.17     $1.07
Diluted earnings per share
  Before cumulative effect of accounting
   changes                                  $1.12    $1.27     $1.01
  Cumulative effect of accounting changes       -    (0.17)        -
  Diluted earnings per share                $1.12    $1.10     $1.01

<FN>
(a) The Series A Preferred Stock and the Series B Preferred
    Stock were not included in the calculation of diluted earnings
    per share because conversion of these shares would be
    antidilutive.
</TABLE>

   Derivative Instruments.  At December 31, 2000, Enron had
derivative instruments (excluding amounts disclosed in Note 10)
on 54.8 million shares of Enron common stock, of which
approximately 12 million shares are with JEDI and 22.5 million
shares are with related parties (see Note 16), at an average
price of $67.92 per share on which Enron was a fixed price
payor.  Shares potentially deliverable to counterparties under the
contracts are assumed to be outstanding in calculating diluted
earnings per share unless they are antidilutive.  At December 31,
2000, there were outstanding non-employee options to purchase 6.4 million
shares of Enron common stock at an exercise price of $19.59 per
share.

   Stock Option Plans.  Enron applies Accounting Principles Board
(APB) Opinion 25 and related interpretations in accounting for
its stock option plans.  In accordance with APB Opinion 25, no
compensation expense has been recognized for the fixed stock
option plans.  Compensation expense charged against income for
the restricted stock plan for 2000, 1999 and 1998 was $220
million, $131 million and $58 million, respectively.  Had
compensation cost for Enron's stock option compensation plans
been determined based on the fair value at the grant dates for
awards under those plans, Enron's net income and earnings per
share would have been $886 million ($1.09 per share basic, $1.01
per share diluted) in 2000, $827 million ($1.08 per share basic,
$1.01 per share diluted) in 1999 and $674 million ($1.02 per
share basic, $0.97 per share diluted) in 1998.

   The fair value of each option grant is estimated on the date
of grant using the Black-Scholes option-pricing model with
weighted-average assumptions for grants in 2000, 1999 and 1998,
respectively:  (i) dividend yield of 2.4%, 2.4% and 2.5%; (ii)
expected volatility of 22.3%, 20.0% and 18.3%; (iii) risk-free
interest rates of 5.8%, 5.6% and 5.0%; and (iv) expected lives of
3.2 years, 3.7 years and 3.8 years.

   Enron has four fixed option plans (the Plans) under which
options for shares of Enron's common stock have been or may be
granted to officers, employees and non-employee members of the
Board of Directors.   Options granted may be either incentive
stock options or nonqualified stock options and are granted at
not less than the fair market value of the stock at the time of
grant.  Under the Plans, Enron may grant options with a maximum
term of 10 years.  Options vest under varying schedules.


   Summarized information for Enron's Plans is as follows:

<TABLE>
<CAPTION>
                             2000                1999               1998
                                 Weighted            Weighted           Weighted
                                 Average             Average            Average
                                 Exercise            Exercise           Exercise
(Shares in thousands)   Shares    Price     Shares    Price     Shares   Price

<S>                    <C>        <C>      <C>        <C>      <C>       <C>
Outstanding,
 beginning of year      93,531    $26.74    79,604    $19.60    78,858   $17.89
  Granted               39,167     70.02    35,118     37.49    15,702    24.99
  Exercised(a)         (32,235)    24.43   (19,705)    18.08   (13,072)   15.70
  Forfeited             (4,358)    35.68    (1,465)    24.51    (1,498)   19.77
  Expired                  (42)    23.75       (21)    18.79      (386)   19.76
Outstanding,
 end of year            96,063    $44.24    93,531     $26.74   79,604   $19.60
Exercisable,
 end of year            46,755    $29.85    52,803     $22.56   45,942   $18.16
Available for grant,
 end of year(b)         22,066              24,864              10,498
Weighted average
 fair value of
 options granted                  $13.35               $ 7.24            $ 4.20

<FN>
(a) In 2000, Enron recorded tax benefits related to stock options
    exercised by employees of approximately $390 million reflected
    in shareholders' equity.
(b) Includes up to 20,707,969 shares, 22,140,962 shares and
    10,497,670 shares as of December 31, 2000, 1999 and 1998,
    respectively, which may be issued either as restricted stock
    or pursuant to stock options.
</TABLE>

   The following table summarizes information about stock options
outstanding at December 31, 2000 (shares in thousands):

<TABLE>
<CAPTION>
                           Options Outstanding            Options Exercisable
                                 Weighted
                                  Average     Weighted                 Weighted
                    Number       Remaining    Average      Number      Average
  Range of        Outstanding   Contractual   Exercise   Exercisable   Exercise
Exercise Prices   at 12/31/00       Life        Price    at 12/31/00     Price

<S>                 <C>             <C>        <C>          <C>         <C>
$ 6.88 to $20.00    15,368          4.7        $16.72       14,001      $16.54
 20.06 to  34.81    24,091          6.8         24.79       18,304       24.13
 35.03 to  47.31    21,520          6.8         40.52        8,731       40.27
 50.48 to  69.00    13,965          6.5         60.18        4,072       61.81
 71.06 to  86.63    21,119          5.6         79.69        1,647       72.36
                    96,063          6.2        $44.24       46,755      $29.85
</TABLE>

   Restricted Stock Plan.  Under Enron's Restricted Stock Plan,
participants may be granted stock without cost to the
participant.  The shares granted under this plan vest to the
participants at various times ranging from immediate vesting to
vesting at the end of a five-year period.  Upon vesting, the
shares are released to the participants.  The following
summarizes shares of restricted stock under this plan:

<TABLE>
<CAPTION>
(Shares in thousands)               2000      1999      1998

<S>                               <C>        <C>       <C>
Outstanding, beginning of year      6,781     6,034     5,074
  Granted                           2,243     2,672     2,122
  Released to participants         (2,201)   (1,702)   (1,064)
  Forfeited                        (1,444)     (223)      (98)
Outstanding, end of year            5,379     6,781     6,034
Available for grant, end of year   20,708    22,141    10,498
Weighted average fair value of
 restricted stock granted         $57.69     $37.38    $23.70
</TABLE>

12  PENSION AND OTHER BENEFITS

   Enron maintains a retirement plan (the Enron Plan) which is a
noncontributory defined benefit plan covering substantially all
employees in the United States and certain employees in foreign
countries.  The benefit accrual is in the form of a cash balance
of 5% of annual base pay.

   Portland General has a noncontributory defined benefit pension
plan (the Portland General Plan) covering substantially all of
its employees.  Benefits under the Portland General Plan are based
on years of service, final average pay and covered compensation.

   Enron Facility Services has a noncontributory defined benefit
pension plan (the EFS Plan) covering substantially all of its
employees.  Benefits under the EFS Plan are based on years
of service, final average pay and covered compensation.

   Enron also maintains a noncontributory employee stock
ownership plan (ESOP) which covers all eligible employees.
Allocations to individual employees' retirement accounts within
the ESOP offset a portion of benefits earned under the Enron
Plan.  All shares included in the ESOP have been allocated to the
employee accounts.  At December 31, 2000 and 1999, 12,600,271
shares and 17,241,731 shares, respectively, of Enron common stock
were held by the ESOP, a portion of which may be used to offset
benefits under the Enron Plan.

   Assets of the Enron Plan, the Portland General Plan and the
EFS Plan are comprised primarily of equity securities, fixed
income securities and temporary cash investments.  It is Enron's
policy to fund all pension costs accrued to the extent required
by federal tax regulations.

   Enron provides certain postretirement medical, life insurance
and dental benefits to eligible employees and their eligible
dependents.  Benefits are provided under the provisions of
contributory defined dollar benefit plans.  Enron is currently
funding that portion of its obligations under these
postretirement benefit plans which are expected to be recoverable
through rates by its regulated pipelines and electric utility
operations.

   Enron accrues these postretirement benefit costs over the
service lives of the employees expected to be eligible to receive
such benefits.  Enron is amortizing the transition obligation
which existed at January 1, 1993 over a period of approximately
19 years.

   The following table sets forth information related to changes
in the benefit obligations, changes in plan assets, a
reconciliation of the funded status of the plans and components
of the expense recognized related to Enron's pension and other
postretirement plans:

<TABLE>
<CAPTION>
                                             Pension Benefits   Other Benefits
(In millions)                                  2000   1999       2000   1999

<S>                                            <C>    <C>        <C>    <C>
Change in benefit obligation
  Benefit obligation, beginning of year        $708   $687       $120   $134
  Service cost                                   33     32          2      2
  Interest cost                                  53     49         10      9
  Plan participants' contributions                -      -          4      3
  Plan amendments                                 -      6          -      -
  Actuarial loss (gain)                           9    (51)        10    (12)
  Acquisitions and divestitures                   -     36          -      -
  Effect of curtailment and settlements(a)       (2)    (8)         -      -
  Benefits paid                                 (55)   (43)       (22)   (16)
Benefit obligation, end of year                $746   $708       $124   $120
Change in plan assets
  Fair value of plan assets, beginning
   of year(b)                                  $853   $774       $ 68   $ 60
  Actual return on plan assets                   41     80         (4)     7
  Acquisitions and divestitures                   -     37          -      -
  Employer contribution                          19      5          7      6
  Plan participants' contributions                -      -          4      3
  Benefits paid                                 (55)   (43)       (11)    (8)
Fair value of plan assets, end of year(b)      $858   $853       $ 64   $ 68
Reconciliation of funded status, end of year
  Funded status, end of year                   $112   $145       $(60)  $(52)
  Unrecognized transition obligation (asset)     (6)   (13)        44     48
  Unrecognized prior service cost                25     32         12     14
  Unrecognized net actuarial loss (gain)         55     11        (17)   (29)
Prepaid (accrued) benefit cost                 $186   $175       $(21)  $(19)
Weighted-average assumptions at December 31
  Discount rate                                7.75%  7.75%      7.75%  7.75%
  Expected return on plan assets (pre-tax)      (c)    (c)        (d)    (d)
  Rate of compensation increase                 (e)    (e)        (e)    (e)
Components of net periodic benefit cost
  Service cost                                 $ 33   $ 32       $  2   $  2
  Interest cost                                  53     49         10      9
  Expected return on plan assets                (75)   (70)        (4)    (4)
  Amortization of transition obligation
   (asset)                                       (6)    (6)         4      4
  Amortization of prior service cost              5      5          1      1
  Recognized net actuarial loss (gain)            -      3         (1)     -
  Effect of curtailment and settlements(a)        -     (6)         -      6
Net periodic benefit cost                      $ 10   $  7       $ 12   $ 18

<FN>
(a) Represents one-time nonrecurring events including the
    exchange and sale of EOG (see Note 2) and certain employees
    ceasing participation in the Portland General Plan as a result of
    union negotiations.
(b) Includes plan assets of the ESOP of $116 million and $121
    million at December 31, 2000 and 1999, respectively.
(c) Long-term rate of return on assets is assumed to be 10.5%
    for the Enron Plan, 9.0% for the Portland General Plan and 9.5%
    for the EFS Plan.
(d) Long-term rate of return on assets is assumed to be 7.5% for
    the Enron assets and 9.5% for the Portland General assets.
(e) Rate of compensation increase is assumed to be 4.0% for the
    Enron Plan, 4.0% to 9.5% for the Portland General Plan and 5.0%
    for the EFS Plan.
</TABLE>

   Included in the above amounts are the unfunded obligations for
the supplemental executive retirement plans.  At both December 31,
2000 and 1999, the projected benefit obligation for these unfunded
plans was $56 million and the fair value of assets was $1 million.

   The measurement date of the Enron Plan and the ESOP is
September 30, and the measurement date of the Portland General
Plan, the EFS Plan and the postretirement benefit plans is
December 31.  The funded status as of the valuation date of the
Enron Plan, the Portland General Plan, the ESOP and the
postretirement benefit plans reconciles with the amount detailed
above which is included in "Other Assets" on the Consolidated
Balance Sheet.

  For measurement purposes, 6% and 10% annual rates of increase
in the per capita cost of covered health care benefits were
assumed for the period 2000 to 2001 for the Enron and Portland
General postretirement plans, respectively.  The rates were assumed
to decrease to 5% by 2002 and 2010 for the Enron and Portland
General postretirement plans, respectively.  Assumed health care
cost trend rates have a significant effect on the amounts reported
for the health care plans.  A one-percentage point change in assumed
health care cost trend rates would have the following effects:

<TABLE>
<CAPTION>
                                               1-Percentage     1-Percentage
(In millions)                                 Point Increase   Point Decrease

<S>                                                <C>             <C>
Effect on total of service and
 interest cost components                          $0.4            $(0.3)
Effect on postretirement benefit obligation        $4.4            $(3.8)
</TABLE>

   Additionally, certain Enron subsidiaries maintain various
incentive based compensation plans for which participants may
receive a combination of cash or stock options, based upon the
achievement of certain performance goals.

13  RATES AND REGULATORY ISSUES

   Rates and regulatory issues related to certain of Enron's
natural gas pipelines and its electric utility operations are
subject to final determination by various regulatory agencies.
The domestic interstate pipeline operations are regulated by the
Federal Energy Regulatory Commission (FERC) and the electric
utility operations are regulated by the FERC and the Oregon
Public Utility Commission (OPUC).  As a result, these operations
are subject to the provisions of Statement of Financial
Accounting Standards (SFAS) No. 71, "Accounting for the Effects
of Certain Types of Regulation," which recognizes the economic
effects of regulation and, accordingly, Enron has recorded
regulatory assets and liabilities related to such operations.

   The regulated pipelines operations' net regulatory assets were
$290 million and $250 million at December 31, 2000 and 1999,
respectively, and are expected to be recovered over varying time
periods.

   The electric utility operations' net regulatory assets were
$450 million and $494 million at December 31, 2000 and 1999,
respectively.  Based on rates in place at December 31, 2000,
Enron estimates that it will collect substantially all of its
regulatory assets within the next 11 years.

   Pipeline Operations.  On April 16, 1999, Northern Natural Gas
Company (Northern) filed an uncontested Stipulation and Agreement
of Settlement (Settlement) with the FERC and an order
approving the Settlement was issued by the FERC on June 18,
1999.  The rates effectuated by Northern on November 1, 1999
remain in effect.  On May 1, 2000, Northern filed to implement an
optional volumetric firm throughput service.  An order approving
such service was issued November 8, 2000 with effectiveness
November 1, 2000; a rehearing request is pending.  On November 1,
2000, Northern filed to increase its rates for the recovery of
return and taxes on its System Levelized Account.  On November
22, 2000, the FERC issued an order approving the rates, subject
to refund.

   On November 1, 2000, Transwestern Pipeline Company implemented
a rate escalation of settled transportation rates in accordance
with its May 1995 global settlement, as amended in May 1996.  On
August 23, 1999, Transwestern filed for a new service, Enhanced
Firm Backhaul.  An order by the FERC was issued February 23,
2000, approving the service.

   Electric Utility Operations.  On October 2, 2000 PGE filed a
restructuring plan with the OPUC that implements the provisions
of the State Senate Bill SB1149, signed into law in July 1999.
The new law provides industrial and commercial customers of
investor-owned utilities in the state direct access to competing
energy suppliers by October 1, 2001.  As filed, PGE's plan also
proposes an increase in base rates, with new tariffs effective on
October 1, 2001.  PGE is a 67.5% owner of the Trojan Nuclear
Plant (Trojan).  In September 2000, PGE entered into an agreement
with the OPUC related to Trojan.  See Note 14.  At December 31,
2000, PGE's regulatory asset related to recovery of Trojan
decommissioning costs from customers was $190 million.

   Enron believes, based upon its experience to date and after
considering appropriate reserves that have been established, that
the ultimate resolution of pending regulatory matters will not
have a material impact on Enron's financial position or results
of operations.

14  LITIGATION AND OTHER CONTINGENCIES

   Enron is a party to various claims and litigation, the
significant items of which are discussed below.  Although no
assurances can be given, Enron believes, based on its experience
to date and after considering appropriate reserves that have been
established, that the ultimate resolution of such items,
individually or in the aggregate, will not have a material
adverse impact on Enron's financial position or results of
operations.

   Litigation.  In 1995, several parties (the Plaintiffs) filed
suit in Harris County District Court in Houston, Texas, against
Intratex Gas Company (Intratex), Houston Pipe Line Company and
Panhandle Gas Company (collectively, the Enron Defendants), each
of which is a wholly-owned subsidiary of Enron.  The Plaintiffs
were either sellers or royalty owners under numerous gas purchase
contracts with Intratex, many of which have terminated.  Early in
1996, the case was severed by the Court into two matters to be
tried (or otherwise resolved) separately.  In the first matter,
the Plaintiffs alleged that the Enron Defendants committed fraud
and negligent misrepresentation in connection with the "Panhandle
program," a special marketing program established in the early
1980s.  This case was tried in October 1996 and resulted in a
verdict for the Enron Defendants.  In the second matter, the
Plaintiffs allege that the Enron Defendants violated state
regulatory requirements and certain gas purchase contracts by
failing to take the Plaintiffs' gas ratably with other producers'
gas at certain times between 1978 and 1988.  The trial court
certified a class action with respect to ratability claims.  On
March 9, 2000, the Texas Supreme Court ruled that the trial
court's class certification was improper and remanded the case to
the trial court.  The Enron Defendants deny the Plaintiffs'
claims and have asserted various affirmative defenses, including
the statute of limitations.  The Enron Defendants believe that
they have strong legal and factual defenses, and intend to
vigorously contest the claims.  Although no assurances can be
given, Enron believes that the ultimate resolution of these
matters will not have a material adverse effect on its financial
position or results of operations.

   On November 21, 1996, an explosion occurred in or around the
Humberto Vidal Building in San Juan, Puerto Rico.  The explosion
resulted in fatalities, bodily injuries and damage to the
building and surrounding property.  San Juan Gas Company, Inc.
(San Juan Gas), an Enron affiliate, operated a propane/air
distribution system in the vicinity, but did not provide service
to the building. Enron, San Juan Gas, four affiliates and their
insurance carriers were named as defendants, along with several
third parties, including The Puerto Rico Aqueduct and Sewer
Authority, Puerto Rico Telephone Company, Heath Consultants
Incorporated, Humberto Vidal, Inc. and their insurance carriers,
in numerous lawsuits filed in U.S. District Court for the
District of Puerto Rico and the Superior Court of Puerto Rico.
These suits seek damages for wrongful death, personal injury,
business interruption and property damage allegedly caused by the
explosion.  After nearly four years without determining the cause
of the explosion, all parties have agreed not to litigate further
that issue, but to move these suits toward settlements or trials
to determine whether each plaintiff was injured as a result of
the explosion and, if so, the lawful damages attributable to such
injury. The defendants have agreed on a fund for settlements or
final awards. Numerous claims have been settled. Although no
assurances can be given, Enron believes that the ultimate
resolution of these matters will not have a material adverse
effect on its financial position or results of operations.

   Trojan Investment Recovery.  In early 1993, PGE ceased commercial
operation of the Trojan nuclear power generating facility.  The OPUC
granted PGE, through a general rate order, recovery of, and a return
on, 87 percent of its remaining investment in Trojan.

   The OPUC's general rate order related to Trojan has been
subject to litigation in various state courts, including rulings
by the Oregon Court of Appeals and petitions to the Oregon
Supreme Court filed by parties opposed to the OPUC's order,
including the Utility Reform Project(URP) and the Citizens
Utility Board (CUB).

   In August 2000, PGE entered into agreements with CUB and the
staff of the OPUC to settle the litigation related to PGE's
recovery of its investment in the Trojan plant.  Under the
agreements, CUB agreed to withdraw from the litigation and to
support the settlement as the means to resolve the Trojan
litigation.  The OPUC approved the accounting and ratemaking
elements of the settlement on September 29, 2000.  As a result of
these approvals, PGE's investment in Trojan is no longer included
in rates charged to customers, either through a return on or a
return of that investment.  Collection of ongoing decommissioning
costs at Trojan is not affected by the settlement agreements or
the September 29, 2000 OPUC order.  With CUB's withdrawal, URP is
the one remaining significant adverse party in the litigation.
URP has indicated that it plans to continue to challenge the OPUC
order allowing PGE recovery of its investment in Trojan.

   Enron cannot predict the outcome of these actions.  Although
no assurances can be given, Enron believes that the ultimate
resolution of these matters will not have a material adverse
effect on its financial position or results of operations.

   Environmental Matters.  Enron is subject to extensive federal,
state and local environmental laws and regulations.  These laws
and regulations require expenditures in connection with the
construction of new facilities, the operation of existing
facilities and for remediation at various operating sites.  The
implementation of the Clean Air Act Amendments is expected to
result in increased operating expenses.  These increased
operating expenses are not expected to have a material impact on
Enron's financial position or results of operations.

   Enron's natural gas pipeline companies conduct soil and
groundwater remediation on a number of their facilities.  Enron
does not expect to incur material expenditures in connection with
soil and groundwater remediation.

15  COMMITMENTS

   Firm Transportation Obligations.  Enron has firm
transportation agreements with various joint venture and
other pipelines.  Under these agreements, Enron must make
specified minimum payments each month.  At December 31, 2000,
the estimated aggregate amounts of such required future payments
were $91 million, $88 million, $89 million, $85 million and $77 million
for 2001 through 2005, respectively, and $447 million for later
years.

   The costs recognized under firm transportation agreements,
including commodity charges on actual quantities shipped, totaled
$68 million, $55 million and $30 million in 2000, 1999 and 1998,
respectively.

   Other Commitments.  Enron leases property, operating
facilities and equipment under various operating leases, certain
of which contain renewal and purchase options and residual value
guarantees.  Future commitments related to these items at
December 31, 2000 were $123 million, $98 million, $69 million,
$66 million and $49 million for 2001 through 2005, respectively,
and $359 million for later years. Guarantees under the leases
total $556 million at December 31, 2000.

   Total rent expense incurred during 2000, 1999 and 1998 was
$143 million, $143 million and $147 million, respectively.

   Enron has entered into two development agreements whereby
Enron is required to manage construction of a certain number of
power projects on behalf of third party owners.  Under one
development agreement, where construction is expected to be
completed on or before March 31, 2004, Enron has agreed to enter
into power offtake agreements for varying portions of the offtake
from each facility.  Under both development agreements, Enron
maintains purchase options, which may be assigned to a third
party.  In addition to the purchase option under the development
agreement, Enron maintains lease options on the power projects.
If upon completion, which is expected to occur on or before August 31,
2002, Enron has failed to exercise one of its options, Enron may
participate in the remarketing of the power projects which Enron
has guaranteed the recovery of 89.9 percent of certain project
costs, of which approximately $140 million has been incurred
through December 31, 2000.

   Enron guarantees the performance of certain of its
unconsolidated equity affiliates in connection with letters of
credit issued on behalf of those entities.  At December 31, 2000,
a total of $264 million of such guarantees were outstanding,
including $103 million on behalf of EOTT Energy Partners, L.P.
(EOTT).  In addition, Enron is a guarantor on certain liabilities
of unconsolidated equity affiliates and other companies totaling
approximately $1,863 million at December 31, 2000, including $538
million related to EOTT trade obligations.  The EOTT letters of
credit and guarantees of trade obligations are secured by the
assets of EOTT.  Enron has also guaranteed $386 million in lease
obligations for which it has been indemnified by an "Investment
Grade" company.  Management does not consider it likely that
Enron would be required to perform or otherwise incur any losses
associated with the above guarantees.  In addition, certain
commitments have been made related to capital expenditures and
equity investments planned in 2001.

   On December 15, 2000, Enron announced that it had entered into
an agreement with Azurix under which the holders of Azurix's
approximately 39 million publicly traded shares would receive cash
of $8.375 in exchange for each share.  The agreement, which is
subject to the approval of Azurix shareholders, is expected to
close in early 2001.

16  RELATED PARTY TRANSACTIONS

   In 2000 and 1999, Enron entered into transactions with limited
partnerships (the Related Party) whose general partner's managing
member is a senior officer of Enron.  The limited partners of the
Related Party are unrelated to Enron.  Management believes that
the terms of the transactions with the Related Party were reasonable
compared to those which could have been negotiated with unrelated
third parties.

   In 2000, Enron entered into transactions with the Related
Party to hedge certain merchant investments and other assets.  As
part of the transactions, Enron (i) contributed to newly-formed
entities (the Entities) assets valued at approximately $1.2
billion, including $150 million in Enron notes payable, 3.7
million restricted shares of outstanding Enron common stock and the
right to receive up to 18.0 million shares of outstanding Enron
common stock in March 2003 (subject to certain conditions) and
(ii) transferred to the Entities assets valued at approximately
$309 million, including a $50 million note payable and an
investment in an entity that indirectly holds warrants
convertible into common stock of an Enron equity method investee.
In return, Enron received economic interests in the Entities,
$309 million in notes receivable, of which $259 million is
recorded at Enron's carryover basis of zero, and a special
distribution from the Entities in the form of $1.2 billion in
notes receivable, subject to changes in the principal for amounts
payable by Enron in connection with the execution of additional
derivative instruments.  Cash in these Entities of $172.6 million
is invested in Enron demand notes.  In addition, Enron paid $123
million to purchase share-settled options from the Entities on
21.7 million shares of Enron common stock.  The Entities paid
Enron $10.7 million to terminate the share-settled options on
14.6 million shares of Enron common stock outstanding.
In late 2000, Enron entered into share-settled collar
arrangements with the Entities on 15.4 million shares of
Enron common stock.  Such arrangements will be accounted
for as equity transactions when settled.

   In 2000, Enron entered into derivative transactions with the
Entities with a combined notional amount of approximately $2.1
billion to hedge certain merchant investments and other assets.
Enron's notes receivable balance was reduced by $36 million as a
result of premiums owed on derivative transactions.  Enron
recognized revenues of approximately $500 million related to the
subsequent change in the market value of these derivatives,
which offset market value changes of certain merchant investments
and price risk management activities.  In addition, Enron recognized
$44.5 million and $14.1 million of interest income and interest expense,
respectively, on the notes receivable from and payable to the
Entities.

   In 1999, Enron entered into a series of transactions
involving a third party and the Related Party. The effect of the
transactions was (i) Enron and the third party amended certain
forward contracts to purchase shares of Enron common stock,
resulting in Enron having forward contracts to purchase Enron
common shares at the market price on that day, (ii) the Related
Party received 6.8 million shares of Enron common stock subject
to certain restrictions and (iii) Enron received a note
receivable, which was repaid in December 1999, and certain
financial instruments hedging an investment held by Enron.  Enron
recorded the assets received and equity issued at estimated fair
value.  In connection with the transactions, the Related Party
agreed that the senior officer of Enron would have no pecuniary
interest in such Enron common shares and would be restricted from
voting on matters related to such shares. In 2000, Enron
and the Related Party entered into an agreement to terminate
certain financial instruments that had been entered into during
1999.  In connection with this agreement, Enron received
approximately 3.1 million shares of Enron common stock held by
the Related Party.  A put option, which was originally entered
into in the first quarter of 2000 and gave the Related Party the
right to sell shares of Enron common stock to Enron at a strike
price of $71.31 per share, was terminated under this agreement.
In return, Enron paid approximately $26.8 million to the Related
Party.

   In 2000, Enron sold a portion of its dark fiber inventory to
the Related Party in exchange for $30 million cash and a $70
million note receivable that was subsequently repaid.  Enron
recognized gross margin of $67 million on the sale.

   In 2000, the Related Party acquired, through securitizations,
approximately $35 million of merchant investments from Enron.  In
addition, Enron and the Related Party formed partnerships in which
Enron contributed cash and assets and the Related Party
contributed $17.5 million in cash.  Subsequently, Enron sold a
portion of its interests in the partnerships through securitizations.
See Note 3.  Also, Enron contributed a put option to a trust in
which the Related Party and Whitewing hold equity and debt interests.
At December 31, 2000, the fair value of the put option was a $36
million loss to Enron.

   In 1999, the Related Party acquired approximately $371 million,
merchant assets and investments and other assets from Enron.  Enron
recognized pre-tax gains of approximately $16 million related to
these transactions.  The Related Party also entered into an agreement
to acquire Enron's interests in an unconsolidated equity affiliate
for approximately $34 million.

17  ASSET IMPAIRMENT

   In 1999, continued significant changes in state and federal
rules regarding the use of MTBE as a gasoline additive have
significantly impacted Enron's view of the future prospects for
this business.  As a result, Enron completed a reevaluation of
its position and strategy with respect to its operated MTBE
assets which resulted in (i) the purchase of certain previously-
leased MTBE related assets, under provisions within the lease, in
order to facilitate future actions, including the potential
disposal of such assets and (ii) a review of all MTBE-related
assets for impairment considering the recent adverse changes and
their impact on recoverability.  Based on this review and
disposal discussions with market participants, in 1999, Enron
recorded a $441 million pre-tax charge for the impairment of its
MTBE-related assets.

18  ACCOUNTING PRONOUNCEMENTS

   Cumulative Effect of Accounting Changes.  In 1999, Enron
recorded an after-tax charge of $131 million to reflect the
initial adoption (as of January 1, 1999) of two new accounting
pronouncements, the AICPA Statement of Position 98-5 (SOP 98-5),
"Reporting on the Costs of Start-Up Activities" and the Emerging
Issues Task Force Issue No. 98-10, "Accounting for Contracts
Involved in Energy Trading and Risk Management Activities."  The
1999 charge was primarily related to the adoption of SOP 98-5.

   Recently Issued Accounting Pronouncements.  In 1998, the
Financial Accounting Standards Board (FASB) issued SFAS No. 133,
"Accounting for Derivative Instruments and Hedging Activities,"
which was subsequently amended by SFAS No. 137 and SFAS No. 138.
SFAS No. 133 must be applied to all derivative
instruments and certain derivative instruments embedded in
hybrid instruments and requires that such instruments be
recorded in the balance sheet either as an asset or liability
measured at its fair value through earnings, with special
accounting allowed for certain qualifying hedges.  Enron will
adopt SFAS No. 133 as of January 1, 2001.  Due to
the adoption of SFAS No. 133, Enron will recognize
an after-tax non-cash loss of approximately $5 million in
earnings and an after-tax non-cash gain in "Other Comprehensive
Income," a component of shareholders' equity, of approximately
$22 million from the cumulative effect of a change in accounting
principle.  Enron will also reclassify $532 million from "Long-
Term Debt" to "Other Liabilities" due to the adoption.

    The total impact of Enron's adoption of SFAS No. 133
on earnings and on "Other Comprehensive Income" is
dependent upon certain pending interpretations, which are
currently under consideration, including those related to
"normal purchases and normal sales" and inflation escalators
included in certain contract payment provisions.  The
interpretations of these issues, and others, are currently under
consideration by the FASB.  While the ultimate conclusions
reached on interpretations being considered by the FASB could
impact the effects of Enron's adoption of SFAS No. 133,
Enron does not believe that such conclusions would have a material
effect on its current estimate of the impact of adoption.

19  QUARTERLY FINANCIAL DATA (Unaudited)

   Summarized quarterly financial data is as follows:

<TABLE>
<CAPTION>
(In millions, except           First    Second     Third    Fourth    Total
 per share amounts)           Quarter   Quarter   Quarter   Quarter   Year(a)

<S>                           <C>       <C>       <C>       <C>       <C>
2000
Revenues                      $13,145   $16,886   $30,007   $40,751   $100,789
Income before
 interest, minority
 interests and income taxes       624       609       666       583      2,482
Net income                        338       289       292        60        979
Earnings per share:
  Basic                       $  0.44   $  0.37   $  0.37   $  0.05   $   1.22
  Diluted                        0.40      0.34      0.34      0.05       1.12

1999
Revenues                      $ 7,632   $ 9,672   $11,835   $10,973   $ 40,112
Income before
 interest, minority
 interests and income taxes       533       469       520       473      1,995
Net income                        122       222       290       259        893
Earnings per share:
  Basic                       $  0.17   $  0.29   $  0.38   $  0.33   $   1.17
  Diluted                        0.16      0.27      0.35      0.31       1.10

<FN>
(a) The sum of earnings per share for the four quarters may not
    equal earnings per share for the total year due to changes in
    the average number of common shares outstanding.
</TABLE>

20  GEOGRAPHIC AND BUSINESS SEGMENT INFORMATION

   Enron's business is divided into operating segments, defined
as components of an enterprise about which financial information
is available and evaluated regularly by the chief operating
decision maker, or decision-making group, in deciding how to
allocate resources to an individual segment and in assessing
performance of the segment.  Enron's chief operating decision-
making group is the Office of the Chairman.

   Enron's chief operating decision-making group evaluates
performance and allocates resources based on income before
interest, minority interests and income taxes (IBIT) as well as
on net income.  Certain costs related to company-wide functions
are allocated to each segment.  However, interest on corporate
debt is primarily maintained at Corporate and is not allocated to
the segments.  Therefore, management believes that IBIT is the
dominant measurement of segment profits consistent with Enron's
consolidated financial statements.  The accounting policies of
the segments are substantially the same as those described in the
summary of significant accounting policies in Note 1.

   Beginning in 2000, Enron's communications business is being
managed as a separate operating segment named Broadband Services
and therefore, based on criteria set by SFAS No. 131,
"Disclosures about Segments of an Enterprise and Related
Information," is reported separately.

   Enron has divided its operations into the following reportable
segments, based on similarities in economic characteristics,
products and services, types of customers, methods of
distributions and regulatory environment.

   Transportation and Distribution - Regulated industries.
Interstate transmission of natural gas.  Management and operation
of pipelines.  Electric utility operations.

   Wholesale Services - Energy commodity sales and services,
risk management products and financial services to wholesale customers.
Development, acquisition and operation of power plants, natural gas
pipelines and other energy-related assets.

   Retail Energy Services - Sales of natural gas and electricity
directly to end-use customers, particularly in the commercial and
industrial sectors, including the outsourcing of energy-related
activities.

   Broadband Services - Construction and management of a
nationwide fiber optic network, the marketing and management of
bandwidth and the delivery of high-bandwidth content.

   Exploration and Production - Natural gas and crude oil
exploration and production primarily in the United States,
Canada, Trinidad and India until August 16, 1999.  See Note 2.

   Corporate and Other - Includes operation of water and
renewable energy businesses as well as clean fuels plants.

   Financial information by geographic and business segment
follows for each of the three years in the period ended December
31, 2000.

Geographic Segments

<TABLE>
<CAPTION>
                                   Year Ended December 31,
(In millions)                      2000      1999      1998

<S>                              <C>        <C>       <C>
Operating revenues from
 unaffiliated customers
  United States                  $ 77,891   $30,176   $25,247
  Foreign                          22,898     9,936     6,013
                                 $100,789   $40,112   $31,260
Income before interest,
 minority interests and income
 taxes
  United States                  $  2,131   $ 1,273   $ 1,008
  Foreign                             351       722       574
                                 $  2,482   $ 1,995   $ 1,582
Long-lived assets
  United States                  $ 10,899   $ 8,286   $ 9,382
  Foreign                             844     2,395     1,275
                                 $ 11,743   $10,681   $10,657
</TABLE>

Business Segments
<TABLE>
<CAPTION>
                                    Transportation                  Retail                Corporate
                                         and           Wholesale    Energy    Broadband      and
(In millions)                        Distribution      Services    Services   Services    Other(d)     Total

<S>                                     <C>             <C>          <C>        <C>        <C>        <C>
2000
Unaffiliated revenues(a)                $2,742          $93,278      $3,824     $  408     $  537     $100,789
Intersegment revenues(b)                   213            1,628         791          -     (2,632)           -
  Total revenues                         2,955           94,906       4,615        408     (2,095)     100,789
Depreciation, depletion and
 amortization                              278              343          38         77        119          855
Operating income (loss)                    565            1,668          58        (64)      (274)       1,953
Equity in earnings of
 unconsolidated equity affiliates           65              486         (60)         1       (405)          87
Gains on sales of assets
 and investments                            25                9          74          -         38          146
Gain on the issuance of stock by
 TNPC, Inc.                                  -                -         121          -          -          121
Interest income                              6              171           5          3         27          212
Other income, net                           71              (74)        (33)         -         (1)         (37)
Income (loss) before interest,
 minority interests and
 income taxes                              732            2,260         165        (60)      (615)       2,482
Capital expenditures                       270            1,280          70        436        325        2,381
Identifiable assets                      7,509           43,920       4,266      1,313      3,201       60,209
Investments in and advances to
 unconsolidated equity affiliates          774            4,014         104         24        378        5,294
  Total assets                          $8,283          $47,934      $4,370     $1,337     $3,579     $ 65,503
</TABLE>

<TABLE>
<CAPTION>
                                    Transportation                   Retail    Exploration     Corporate
                                         and           Wholesale     Energy        and            and
(In millions)                        Distribution      Services     Services   Production(c)    Other(d)     Total

<S>                                     <C>             <C>          <C>          <C>           <C>         <C>
1999
Unaffiliated revenues(a)                $2,013          $35,501      $1,518       $  429        $  651      $40,112
Intersegment revenues(b)                    19              786         289           97        (1,191)           -
  Total revenues                         2,032           36,287       1,807          526          (540)      40,112
Depreciation, depletion and
 amortization                              247              294          29          213            87          870
Operating income (loss)                    551              889         (81)          66          (623)         802
Equity in earnings of
 unconsolidated equity affiliates           50              237           -            -            22          309
Gains on sales of assets
 and investments                            19               11           -            -           511          541
Interest income                             20              126           5            -            11          162
Other income, net                           45               54           8           (1)           75          181
Income (loss) before interest,
 minority interests and
 income taxes                              685            1,317         (68)          65            (4)      1,995
Capital expenditures                       316            1,216          64          226            541      2,363
Identifiable assets                      7,148           18,501         956            -          1,740     28,345
Investments in and advances to
 unconsolidated equity affiliates          811            2,684           -            -          1,541      5,036
  Total assets                          $7,959          $21,185      $  956       $    -         $3,281    $33,381

1998
Unaffiliated revenues(a)                $1,833          $27,220      $1,072       $  750         $  385    $31,260
Intersegment revenues(b)                    16              505           -          134           (655)         -
  Total revenues                         1,849           27,725       1,072          884           (270)    31,260
Depreciation, depletion and
 amortization                              253              195          31          315             33        827
Operating income (loss)                    562              880        (124)         133            (73)     1,378
Equity in earnings of
 unconsolidated equity affiliates           33               42          (2)           -             24         97
Gains on sales of assets
 and investments                            31                4           -            -             21         56
Interest income                              9               67           -            1             11         88
Other income, net                            2              (25)          7           (6)           (15)       (37)
Income (loss) before interest,
 minority interests and
 income taxes                              637              968        (119)         128            (32)     1,582
Capital expenditures                       310              706          75          690            124      1,905
Identifiable assets                      6,955           12,205         747        3,001          2,009     24,917
Investments in and advances to
 unconsolidated equity affiliates          661            2,632           -            -          1,140     4,433
  Total assets                          $7,616          $14,837      $  747       $3,001         $3,149   $29,350

<FN>
(a) Unaffiliated revenues include sales to unconsolidated equity
    affiliates.
(b) Intersegment sales are made at prices comparable to those
    received from unaffiliated customers and in some instances are
    affected by regulatory considerations.
(c) Reflects results through August 16, 1999.  See Note 2.
(d) Includes consolidating eliminations.
</TABLE>

<PAGE>
          REPORT OF INDEPENDENT PUBLIC ACCOUNTANTS
               ON FINANCIAL STATEMENT SCHEDULE


To the Shareholders and Board of Directors of Enron Corp.:

We have audited in accordance with generally accepted
auditing standards, the consolidated financial statements of
Enron Corp. and subsidiaries included in this Form 10-K and
have issued our report thereon dated February 23, 2001.  Our
audit was made for the purpose of forming an opinion on the
basic financial statements taken as a whole.  The schedule
listed in Item 14(a)2 is the responsibility of the company's
management and is presented for purposes of complying with
the Securities and Exchange Commission's rules and is not
part of the basic financial statements.  This schedule has
been subjected to the auditing procedures applied in the
audit of the basic financial statements and, in our opinion,
fairly states in all material respects the financial data
required to be set forth therein in relation to the basic
financial statements taken as a whole.



                       Arthur Andersen LLP

Houston, Texas
February 23, 2001


<PAGE>
<TABLE>
                                                                SCHEDULE II

                       ENRON CORP. AND SUBSIDIARIES
              SCHEDULE II - VALUATION AND QUALIFYING ACCOUNTS
           FOR THE YEARS ENDED DECEMBER 31, 2000, 1999 AND 1998
                               (In Millions)

<CAPTION>
       Column A                   Column B         Column C              Column D       Column E
                                                   Additions            Deductions
                                 Balance at   Charged to   Charged    For Purpose For
                                 Beginning    Costs and    to Other   Which Reserves   Balance at
     Description                  of Year     Expenses     Accounts    Were Created    End of Year

<S>                                <C>          <C>          <C>           <C>           <C>
2000
Reserves deducted from
 assets from price risk
 management activities             $337         $299         $ 75          $259          $452

Reserves for regulatory issues      201           35           29           231            34

Other reserves(a)                    48          125            9            21           161

1999
Reserves deducted from
 assets from price risk
 management activities             $325         $185         $ 19          $192          $337

Reserves for regulatory issues      247           35           23           104           201

Other reserves(a)                    49           27            9            37            48

1998
Reserves deducted from
 assets from price risk
 management activities             $282        $141         $  -           $ 98          $325

Reserves for regulatory issues      262          15           27             57           247

Other reserves(a)                    45          20            1             17            49

<FN>
(a) Primarily consists of allowance for doubtful accounts and reserve for
    insurance claims and losses.
</TABLE>



<PAGE>
                         SIGNATURES


     Pursuant to the requirements of Section 13 or 15(d) of
the Securities Exchange Act of 1934, the Registrant has duly
caused this Report to be signed on its behalf by the
undersigned, thereunto duly authorized, on this 30th day of
March, 2001.

                              ENRON CORP.
                              (Registrant)



                              By:  RICHARD A. CAUSEY
                                   (Richard A. Causey)
                                   Executive Vice President
                                   and Chief Accounting Officer


     Pursuant to the requirements of the Securities Exchange
Act of 1934, this Report has been signed below on March 30,
2001 by the following persons on behalf of the Registrant
and in the capacities indicated.


       Signature                  Title

     JEFFREY  K. SKILLING     Chief Executive Officer and
     (Jeffrey K. Skilling)    Director
                              (Principal Executive Officer)

     RICHARD A. CAUSEY        Executive Vice President and
     (Richard A. Causey)      Chief Accounting Officer
                              (Principal Accounting Officer)

      ANDREW S. FASTOW        Executive Vice President and
     (Andrew S. Fastow)       Chief Financial Officer
                              (Principal Financial Officer)

     ROBERT A. BELFER*        Director
    (Robert A. Belfer)

    NORMAN P. BLAKE, JR.*     Director
   (Norman P. Blake, Jr.)

      RONNIE C. CHAN*         Director
     (Ronnie C. Chan)

      JOHN H. DUNCAN*         Director
     (John H. Duncan)

     WENDY L. GRAMM*          Director
    (Wendy L. Gramm)

    KEN L. HARRISON*          Director
   (Ken L. Harrison)

    ROBERT K. JAEDICKE*       Director
   (Robert K. Jaedicke)

     KENNETH  L.  LAY*        Chairman of the Board and
     (Kenneth L. Lay)         Director


   CHARLES A. LeMAISTRE*      Director
  (Charles A. LeMaistre)

    JOHN MENDELSOHN*          Director
   (John Mendelsohn)

     JEROME J. MEYER*         Director
    (Jerome J. Meyer)

  PAULO V. FERRAZ PEREIRA*    Director
 (Paulo V. Ferraz Pereira)

     FRANK SAVAGE*            Director
    (Frank Savage)

     JOHN A. URQUHART*        Director
    (John A. Urquhart)

      JOHN WAKEHAM*           Director
     (John Wakeham)

   HERBERT S. WINOKUR, JR.*   Director
  (Herbert S. Winokur, Jr.)




*By:  REBECCA C. CARTER
     (Rebecca C. Carter)
(Attorney-in-fact for persons indicated)



               SECURITIES AND EXCHANGE COMMISSION
                    WASHINGTON, D.C.  20549
                     ______________________


                          EXHIBITS TO
                           FORM 10-K


         ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(D)
             OF THE SECURITIES EXCHANGE ACT OF 1934



For the fiscal year ended December 31, 2000
Commission File Number 1-13159




                          ENRON CORP.
     (Exact name of Registrant as specified in its charter)



        OREGON                                   47-0255140
(State or other jurisdiction of                (IRS Employer
incorporation  or organization)               Identification No.)




                       1400 Smith Street
                      Houston, Texas 77002
            (Address of principal executive offices)
Registrant's Telephone Number, Including Area Code (713) 853-616
1
                 _____________________________

                         EXHIBIT INDEX

Exhibit
Number                          Description

*3.01  -  Amended and Restated Articles of Incorporation of
          Enron Oregon Corp. (Annex E to the Proxy
          Statement/Prospectus included in Enron's
          Registration Statement on Form S-4 - File No. 333-
          13791).

 *3.02  - Articles of Merger of Enron Oregon Corp., an Oregon
          corporation, and Enron Corp., a Delaware
          corporation (Exhibit 3.02 to Post-Effective
          Amendment No. 1 to Enron's Registration Statement
          on Form S-3 - File No. 33-60417).

 *3.03  - Articles of Merger of Enron Corp., an Oregon
          corporation, and Portland General Corporation, an
          Oregon corporation (Exhibit 3.03 to Post-Effective
          Amendment No. 1 to Enron's Registration Statement
          on Form S-3 - File No. 33-60417).

 *3.04  - Bylaws of Enron (Exhibit 3.04 to Post-Effective
          Amendment No. 1 to Enron's Registration Statement
          on Form S-3 - File No. 33-60417).

 *3.05  - Articles of Amendment of Enron:  Form of Series
          Designation for the Enron Convertible Preferred
          Stock (Annex F to the Proxy Statement/Prospectus
          included in Enron's Registration Statement on Form
          S-4 - File No. 333-13791).

 *3.06  - Articles of Amendment of Enron:  Form of Series
          Designation for the Enron 9.142% Preferred Stock
          (Annex G to the Proxy Statement/Prospectus included
          in Enron's Registration Statement on Form S-4 -
          File No. 333-13791).

 *3.07  - Articles of Amendment of Enron:  Statement of
          Resolutions Establishing Series A Junior Voting
          Convertible Preferred Stock (Exhibit 3.07 to
          Enron's Registration Statement on Form S-3 - File
          No. 333-44133).

 *3.08  - Articles of Amendment of Enron:  Statement of
          Resolutions Establishing A Series of Preferred
          Stock of Enron Corp. - Mandatorily Convertible
          Single Reset Preferred Stock, Series A (Exhibit
          4.01 to Enron's Form 8-K filed on January 26,
          1999).

 *3.09  - Articles of Amendment of Enron:  Statement of
          Resolutions Establishing A Series of Preferred
          Stock of Enron Corp. - Mandatorily Convertible
          Single Reset Preferred Stock, Series B (Exhibit
          4.02 to Enron's Form 8-K filed on January 26,
          1999).

 *3.10  - Articles of Amendment of Enron amending Article IV
          of the Articles of Incorporation (Exhibit 3.10 to
          Post-Effective Amendment No. 1 to Enron's
          Registration Statement on Form S-3 - File No. 333-
          70465).

 *3.11  - Articles of Amendment of Enron:  Statement of
          Resolutions Establishing A Series of Preferred
          Stock of Enron Corp. - Mandatorily Convertible
          Junior Preferred Stock, Series B (Exhibit 3.11 to
          Post-Effective Amendment No. 1 to Enron's
          Registration Statement on Form S-3 - File No. 333-
          70465).

 *4.01  - Indenture dated as of November 1, 1985, between
          Enron and Harris Trust and Savings Bank (now The
          Bank of New York), as supplemented and amended by
          the First Supplemental Indenture dated as of
          December 1, 1995 (Form T-3 Application for
          Qualification of Indentures under the Trust
          Indenture Act of 1939, File No. 22-14390, filed
          October 24, 1985; Exhibit 4(b) to Form S-3
          Registration Statement No. 33-64057 filed on
          November 8, 1995).  There have not been filed as
          exhibits to this Form 10-K other debt instruments
          defining the rights of holders of long-term debt of
          Enron, none of which relates to authorized
          indebtedness that exceeds 10% of the consolidated
          assets of Enron and its subsidiaries.  Enron hereby
          agrees to furnish a copy of any such instrument to
          the Commission upon request.

 *4.02 -  Supplemental Indenture, dated as of May
          8, 1997, by and among Enron Corp., Enron Oregon
          Corp. and Harris Trust and Savings Bank (now The
          Bank of New York), as Trustee (Exhibit 4.02 to Post-
          Effective Amendment No. 1 to Enron's Registration
          Statement on Form S-3, File No. 33-60417).

 *4.03  - Third Supplemental Indenture, dated as of September
          1, 1997, between Enron Corp. and Harris Trust and
          Savings Bank (now The Bank of New York), as Trustee
          (Exhibit 4.03 to Enron Registration Statement on
          Form S-3, File No. 333-35549).

 *4.04  - Fourth Supplemental Indenture, dated as of August
          17, 1999, between Enron Corp. and Harris Trust and
          Savings Bank (now The Bank of New York), as Trustee
          (Exhibit 4.05 to Enron Registration Statement on
          Form S-3 - File No. 333-83549).

Executive Compensation Plans and Arrangements Filed as
Exhibits Pursuant to Item 14(c) of Form 10-K:  Exhibits 10.01
through 10.53

*10.01  - Enron Executive Supplemental Survivor Benefits
          Plan, effective January 1, 1987 (Exhibit 10.01 to
          Enron Form 10-K for 1992).

*10.02  - First Amendment to Enron Executive
          Supplemental Survivor Benefits Plan (Exhibit 10.02
          to Enron Form 10-K for 1999).

*10.03  - Enron Corp. 1988 Stock Plan (Exhibit 4.3 to Form S-
          8 Registration Statement No. 33-27893).

*10.04  - Second Amendment to Enron Corp. 1988 Stock Plan
          (Exhibit 10.04 to Enron Form 10-K for 1996).

*10.05  - Enron Corp. 1988 Deferral Plan (Exhibit 10.19 to
          Enron Form 10-K for 1987).

*10.06  - First Amendment to Enron Corp. 1988 Deferral Plan
          (Exhibit 10.06 to Enron Form 10-K for 1995).

*10.07  - Second Amendment to Enron Corp. 1988 Deferral Plan
          (Exhibit 10.07 to Enron Form 10-K for 1995).

*10.08  - Third Amendment to Enron Corp. 1988 Deferral Plan
          (Exhibit 10.09 to Enron Form 10-K for 1996).

*10.09  - Fourth Amendment to Enron Corp. 1988 Deferral Plan
          (Exhibit 10.10 to Enron Form 10-K for 1996).

*10.10  - Fifth Amendment to Enron Corp. 1988 Deferral Plan
          (Exhibit 10.11 to Enron Form 10-K for 1996).

*10.11  - Sixth Amendment to Enron Corp. 1988 Deferral Plan
          (Exhibit 10.11 to Enron Form 10-K for 1999).

*10.12  - Enron Corp. 1991 Stock Plan (Exhibit 10.08 to Enron
          Form 10-K for 1991).

*10.13  - Amended and Restated Enron Corp. 1991 Stock Plan
          (Exhibit A to Enron Proxy Statement filed pursuant
          to Section 14(a) on March 24, 1997).

*10.14  - First Amendment to Enron Corp. Amended and Restated
          1991 Stock Plan (Exhibit 10.13 to Enron Form 10-K
          for 1997).

*10.15  - Second Amendment to Enron Corp. Amended and
          Restated 1991 Stock Plan (Exhibit 10.14 to Enron
          Form 10-K for 1997).

*10.16  - Enron Corp. 1991 Stock Plan (As Amended and
          Restated Effective May 4, 1999) (Exhibit B to Enron
          Proxy Statement filed pursuant to Section 14(a) on
          March 30, 1999).

*10.17  - First Amendment to Enron Corp. 1991 Stock Plan (As
          Amended and Restated Effective May 4, 1999)
          (Exhibit 10.17 to Enron Form 10-K for 1999).

*10.18  - Second Amendment to Enron Corp. 1991 Stock Plan (As
          Amended and Restated Effective May 4, 1999)
          (Exhibit 10.18 to Enron Form 10-K for 1999).

*10.19  - Third Amendment to Enron Corp. 1991 Stock Plan (As
          Amended and Restated Effective May 4, 1999)
          (Exhibit 10.19 to Enron Form 10-K for 1999).

*10.20  - Enron Corp. 1992 Deferral Plan (Exhibit 10.09 to
          Enron Form 10-K for 1991).

*10.21  - First Amendment to Enron Corp. 1992 Deferral Plan
          (Exhibit 10.10 to Enron Form 10-K for 1995).

*10.22  - Second Amendment to Enron Corp. 1992 Deferral Plan
          (Exhibit 10.11 to Enron Form 10-K for 1995).

*10.23  - Enron Corp. Directors' Deferred Income Plan
          (Exhibit 10.09 to Enron Form 10-K for 1992).

*10.24  - Split Dollar Life Insurance Agreement between Enron
          and the KLL and LPL Family Partnership, Ltd., dated
          April 22, 1994 (Exhibit 10.17 to Enron Form 10-K
          for 1994).

*10.25  - Employment Agreement between Enron Corp. and
          Kenneth L. Lay, executed December 18, 1996 (Exhibit
          10.25 to Enron Form 10-K for 1996).

*10.26  - First Amendment to Employment Agreement between
          Enron Corp. and Kenneth L. Lay, dated February 7,
          2000 (Exhibit 10.26 to Enron Form 10-K for 1999).

*10.27  - Consulting Services Agreement between Enron and
          John A. Urquhart dated August 1, 1991 (Exhibit
          10.23 to Enron Form 10-K for 1991).

*10.28  - First Amendment to Consulting Services Agreement
          between Enron and John A. Urquhart, dated August
          27, 1992 (Exhibit 10.25 to Enron Form 10-K for
          1992).

*10.29  - Second and Third Amendments to Consulting Services
          Agreement between Enron and John A. Urquhart, dated
          November 24, 1992 and February 26, 1993,
          respectively (Exhibit 10.26 to Enron Form 10-K for
          1992).

*10.30  - Fourth Amendment to Consulting Services Agreement
          between Enron and John A. Urquhart dated as of May
          9, 1994 (Exhibit 10.35 to Enron Form 10-K for
          1995).

*10.31 -  Fifth Amendment to Consulting Services Agreement
          between Enron and John A. Urquhart (Exhibit 10.36
          to Enron Form 10-K for 1995).

*10.32  - Sixth Amendment to Consulting Services Agreement
          between Enron and John A. Urquhart (Exhibit 10.37
          to Enron Form 10-K for 1995).

*10.33  - Seventh Amendment to Consulting Services Agreement
          between Enron and John A. Urquhart, dated October
          27, 1997 (Exhibit 10.27 to Enron Form 10-K for
          1997).

*10.34  - Eighth Amendment to Consulting Services Agreement
          between Enron and John A. Urquhart, dated May 27,
          1998 (Exhibit 10.28 to Enron Form 10-K for 1998).

*10.35  - Ninth Amendment to Consulting Services Agreement
          between Enron and John A. Urquhart, dated December
          31, 1998 (Exhibit 10.29 to Enron Form 10-K for
          1998).

*10.36  - Tenth Amendment to Consulting Services Agreement
          between John A. Urquhart and Enron Corp. dated
          January 1, 2000 (Exhibit 10.36 to Enron Form 10-K
          for 1999).

*10.37  - Enron Corp. Performance Unit Plan (Exhibit A to
          Enron Proxy Statement filed pursuant to Section
          14(a) on March 25, 1994).

*10.38  - Enron Corp. Annual Incentive Plan (Exhibit B to
          Enron Proxy Statement filed pursuant to Section
          14(a) on March 25, 1994).

*10.39  - Enron Corp. Annual Incentive Plan dated May 4, 1999
          (Exhibit A to Enron Proxy Statement filed pursuant
          to Section 14(a) on March 30, 1999).

*10.40  - Enron Corp. Performance Unit Plan (as amended and
          restated effective May 2, 1995) (Exhibit A to Enron
          Proxy Statement filed pursuant to Section 14(a) on
          March 27, 1995).

*10.41  - First Amendment to Enron Corp. Performance Unit
          Plan (Exhibit 10.46 to Enron Form 10-K for 1995).

*10.42  - Enron Corp. Restated 1994 Deferral Plan (Exhibit
          4.3 to Enron Form S-8 Registration Statement, File
          No. 333-48193).

*10.43  - Employment Agreement between Enron Capital Trade &
          Resources Corp. and Jeffrey K. Skilling, dated
          January 1, 1996 (Exhibit 10.63 to Enron Form 10-K
          for 1996).

*10.44  - First Amendment effective January 1, 1997, by and
          among Enron Corp., Enron Capital & Trade Resources
          Corp., and Jeffrey K. Skilling, amending Employment
          Agreement between Enron Capital & Trade Resources
          Corp. and Jeffrey K. Skilling dated January 1, 1996
          (Exhibit 10.64 to Enron Form 10-K for 1996).

*10.45  - Split Dollar Agreement between Enron and Jeffrey K.
          Skilling dated May 23, 1997 (Exhibit 10.41 to Enron
          Form 10-K for 1997).

*10.46  - Second Amendment effective October 13, 1997, to
          Employment Agreement between Enron Corp. and
          Jeffrey K. Skilling (Exhibit 10.42 to Enron Form 10-
          K for 1997).

*10.47  - Loan Agreement effective October 13, 1997, between
          Enron Corp. and Jeffrey K. Skilling (Exhibit 10.43
          to Enron Form 10-K for 1997).

*10.48  - Third Amendment to Employment Agreement between
          Enron Corp. and Jeffrey K. Skilling, dated February
          7, 2000 (Exhibit 10.48 to Enron Form 10-K for
          1999).

*10.49  - Executive Employment Agreement between Enron
          Operations Corp. and Stanley C. Horton, dated as
          of October 1, 1999 (Exhibit 10.45 to Enron Form 10-
          K for 1997).

*10.50  - First Amendment to Executive Employment Agreement
          by and between Enron Operations Corp., Enron Corp.
          and Stanley C. Horton, dated December 27, 1999
          (Exhibit 10.56 to Enron Form 10-K for 1999).

 10.51  - Employment Agreement between Enron Corp. and Mark
          A. Frevert, effective March 1, 2000

*10.52  - Executive Employment Agreement between Enron Corp.
          and Kenneth D. Rice, effective June 1, 1998
          (Exhibit 10.43 to Enron Form 10-K for 1998).

 10.53  - First Amendment to Executive Employment Agreement
          between Enron Corp. and Kenneth D. Rice, dated
          February 14, 2000.

 12     - Statement re computation of ratios of earnings
          to fixed charges.

 21     - Subsidiaries of registrant.

 23.01  - Consent of Arthur Andersen LLP.

 23.02  - Consent of Arthur Andersen LLP.

 24     - Powers of Attorney for the directors signing
          this Form 10-K.

 99     - Financial Statements of Atlantic Water Trust.


         *    Asterisk indicates exhibits incorporated
              by reference.